Apparatuses, systems, and methods for improving downhole separation of gases from liquids while producing reservoir fluid

ABSTRACT

A reservoir fluid production system for producing reservoir fluid from a subterranean formation is provided for mitigating gas interference by effecting downhole separation of a gaseous phase from reservoir fluids, while mitigating entrainment of liquid hydrocarbon material within the gaseous phase.

FIELD

The present disclosure relates to mitigating downhole pump gasinterference during hydrocarbon production.

BACKGROUND

Downhole pump gas interference is a problem encountered while producingwells, especially wells with horizontal sections. In producing reservoirfluids containing a significant fraction of gaseous material, thepresence of such gaseous material hinders production by contributing tosluggish flow.

SUMMARY

In one aspect, there is provided a reservoir fluid conduction assemblyfor disposition within a wellbore string, that is lining a wellbore thatis extending into a subterranean formation, such that an intermediatewellbore space is defined within a space that is disposed between thewellbore string and the assembly, wherein the assembly includes:

a reservoir fluid-supplying conductor for conducting reservoir fluidthat is being received from a downhole wellbore space of the wellbore;

a flow diverter body including (a) a diverter body-defined reservoirfluid conductor for conducting reservoir fluid, that is supplied fromthe reservoir fluid-supplying conductor, to a reservoir fluid separationspace of an uphole wellbore space of the wellbore, the uphole wellborespace being disposed uphole relative to the downhole wellbore space, and(b) a diverter body-defined gas-depleted reservoir fluid conductor forreceiving gas-depleted reservoir fluid and conducting the receivedgas-depleted reservoir fluid for effecting supplying of the gas-depletedreservoir fluid to a gas-depleted reservoir fluid-producing conductor;

a sealed interface effector for co-operating with the wellbore stringfor establishing a sealed interface a sealed interface for preventing,or substantially preventing, bypassing of the diverter body-definedgas-depleted reservoir fluid conductor by the separated gas-depletedreservoir fluid; and

an anchor for coupling the assembly to the wellbore string;

wherein:

-   -   the flow diverter body, the sealed interface effector, the        reservoir fluid-supplying conductor, and the anchor are        co-operatively configured such that, while the assembly is        coupled to the wellbore string by the anchor, and disposed        within the wellbore string such that the sealed interface is        defined, and the reservoir fluid-supplying conductor is        receiving reservoir fluid from the downhole wellbore space that        has been received within the downhole wellbore space from the        subterranean formation:        -   the reservoir fluid is conducted to the diverter            body-defined reservoir fluid conductor via the reservoir            fluid-supplying conductor;        -   the reservoir fluid is conducted by the diverter            body-defined reservoir fluid conductor and discharged to a            reservoir fluid separation space of the uphole wellbore            space;        -   within the reservoir fluid separation space, a gas-depleted            reservoir fluid and a gaseous material are separated from            the discharged reservoir fluid, in response to at least            buoyancy forces, such that the gas-depleted reservoir fluid            and the separated gaseous material are obtained;        -   the separated gas-depleted reservoir fluid is conducted to            the diverter body-defined gas-depleted reservoir fluid            conductor, via the intermediate wellbore space, for            conduction to the surface via a gas-depleted reservoir fluid            producing conductor; and        -   the separated gaseous material is conducted to the surface            via the intermediate wellbore space, and there is an            absence, or substantial absence, of opposition to conduction            of the separated gaseous material to the surface, via the            intermediate wellbore space, by the anchor;    -   and    -   the reservoir fluid separation space defines a        separation-facilitating space portion of the intermediate        wellbore space.

In another aspect, there is provided a reservoir fluid conductionassembly for disposition within a wellbore string, that is lining awellbore that is extending into a subterranean formation, wherein theassembly includes:

a reservoir fluid-supplying conductor for conducting reservoir fluidthat is being received from the subterranean formation;

a gas separator, fluidly coupled to the reservoir fluid-supplyingconductor for receiving the reservoir fluid conducted by the reservoirfluid-supplying conductor, and effecting separation of gaseous materialfrom the reservoir fluid such that a gaseous-depleted reservoir fluidand a gaseous material are obtained; and

an anchor for coupling the assembly to the wellbore string;

wherein:

-   -   the gas separator, the reservoir fluid-supplying conductor, and        the anchor are co-operatively configured such that, while the        assembly is coupled to the wellbore string by the anchor, and        the reservoir fluid-supplying conductor is receiving reservoir        fluid from the downhole wellbore space that has been received        within the downhole wellbore space from the subterranean        formation:        -   the reservoir fluid is conducted to the separator via the            reservoir fluid-supplying conductor;        -   a gas-depleted reservoir fluid and a gaseous material are            separated from the discharged reservoir fluid by the            separator; and        -   the separated gaseous material is conducted to the surface            via the wellbore, wherein there is an absence, or            substantial absence, of opposition to flow of the separated            gaseous material to the surface, via the wellbore, by the            anchor.

In another aspect, there is provided a reservoir fluid production systemfor producing reservoir fluid from a subterranean formation, comprising:

a wellbore;

a wellbore string that is lining the wellbore;

wherein:

-   -   the wellbore includes a wellbore space; and    -   the wellbore space includes a downhole wellbore space and an        uphole wellbore space, wherein the uphole wellbore space is        disposed uphole relative to the downhole wellbore space;

and

a reservoir fluid conduction assembly disposed within wellbore stringand including:

-   -   a reservoir fluid-supplying conductor for receiving reservoir        fluid from the downhole wellbore space;    -   a gas-depleted reservoir fluid conductor for receiving a        gas-depleted reservoir fluid;    -   an anchor for coupling the assembly to the wellbore string;

wherein:

-   -   the wellbore string and the assembly are co-operatively        configured such that, while the downhole wellbore space is        receiving reservoir fluid from the subterranean formation:        -   the reservoir fluid is conducted by the reservoir            fluid-supplying conductor to a reservoir fluid separation            space of the uphole wellbore space with effect that a            gas-depleted reservoir fluid and a gaseous material are            separated from the reservoir fluid within the reservoir            fluid separation space, in response to at least buoyancy            forces, such that the gas-depleted reservoir fluid and the            gaseous material are obtained;        -   the gas-depleted reservoir material is conducted to the            gas-depleted reservoir fluid conductor with effect that the            gas-depleted reservoir fluid is conducted through the            gas-depleted reservoir fluid conductor to the surface; and        -   the separated gaseous material is conducted to the surface            via the intermediate wellbore space, and there is an            absence, or substantial absence, of opposition to conduction            of the separated gaseous material to the surface, via the            intermediate wellbore space, by the anchor.

In another aspect, there is provided a system including a reservoirfluid conduction assembly disposed within a wellbore string, that islining a wellbore that is extending into a subterranean formation, suchthat an intermediate wellbore space is defined within a space that isdisposed between the wellbore string and the assembly, wherein theassembly includes:

a reservoir fluid-supplying conductor for conducting reservoir fluidthat is being received from a downhole wellbore space of the wellbore;

a flow diverter body including (a) a diverter body-defined reservoirfluid conductor for conducting reservoir fluid, that is supplied fromthe reservoir fluid-supplying conductor, to a reservoir fluid separationspace of an uphole wellbore space of the wellbore, the uphole wellborespace being disposed uphole relative to the downhole wellbore space, and(b) a diverter body-defined gas-depleted reservoir fluid conductor forreceiving gas-depleted reservoir fluid and conducting the receivedgas-depleted reservoir fluid for effecting supplying of the gas-depletedreservoir fluid to a gas-depleted reservoir fluid-producing conductor;and

a sealed interface for preventing, or substantially preventing,bypassing of the diverter body-defined reservoir fluid conductor by theseparated gas-depleted reservoir fluid;

wherein:

-   -   the flow diverter body, the sealed interface effector, and the        reservoir fluid-supplying conductor are co-operatively        configured such that, while the reservoir fluid-supplying        conductor is receiving reservoir fluid from the downhole        wellbore space that has been received within the downhole        wellbore space from the subterranean formation:        -   the reservoir fluid is conducted to the diverter            body-defined reservoir fluid conductor via the reservoir            fluid-supplying conductor;        -   the reservoir fluid is conducted by the diverter            body-defined reservoir fluid conductor and discharged to a            reservoir fluid separation space of the uphole wellbore            space;        -   within the reservoir fluid separation space, a gas-depleted            reservoir fluid is separated from the discharged reservoir            fluid, in response to at least buoyancy forces; and        -   the separated gas-depleted reservoir fluid is conducted to            the diverter body-defined gas-depleted reservoir            fluid-diverting conductor, via the intermediate wellbore            space, for conduction to the surface via a gas-depleted            reservoir fluid producing conductor;    -   the reservoir fluid separation space defines a        separation-facilitating space portion of the intermediate        wellbore space;    -   the reservoir fluid-suppling conductor includes:        -   a vertical section-disposed portion having a central            longitudinal axis that is less than 20 degrees relative to            the vertical;        -   a horizontal-section disposed portion having a central            longitudinal axis that is between 70 and 110 degrees            relative to the vertical; and        -   a transition section-disposed portion disposed between the            vertical section-disposed portion and the horizontal            section-disposed portion    -   and    -   a cross-sectional area of the fluid passage of the transition        section-disposed portion is less than both of: (i) a        cross-sectional area of the fluid passage of the vertical        section-disposed portion, and (ii) a cross-sectional area of the        fluid passage of the horizontal section-disposed portion.

In another aspect, there is provided a system including a reservoirfluid-supplying conductor, disposed within a wellbore, and including:

-   -   a conductor inlet for receiving reservoir fluid flow from the        wellbore;    -   a vertical section-disposed portion having a central        longitudinal axis that is less than 20 degrees relative to the        vertical;    -   a horizontal section-disposed portion having a central        longitudinal axis that is between 70 and 110 degrees relative to        the vertical; and    -   a transition section-disposed portion that is disposed between        the vertical and horizontal sections;

wherein a cross-sectional area of the fluid passage of the transitionsection-disposed portion is less than both of: (i) a cross-sectionalarea of the fluid passage of the vertical section-disposed portion, and(ii) a cross-sectional area of the fluid passage of the horizontalsection-disposed portion.

In another aspect, there is provided a reservoir fluid conductionassembly for disposition within a wellbore string, that is lining awellbore that is extending into a subterranean formation, such that anintermediate wellbore space is defined within a space that is disposedbetween the wellbore string and the assembly, wherein the assemblyincludes:

a reservoir fluid-supplying conductor for conducting reservoir fluidthat is being received from a downhole wellbore space of the wellbore;

a flow diverter body including (a) a diverter body-defined reservoirfluid conductor for conducting reservoir fluid, that is supplied fromthe reservoir fluid-supplying conductor, to a reservoir fluid separationspace of an uphole wellbore space of the wellbore, the uphole wellborespace being disposed uphole relative to the downhole wellbore space, and(b) a diverter body-defined gas-depleted reservoir fluid conductor forreceiving gas-depleted reservoir fluid and conducting the receivedgas-depleted reservoir fluid for effecting supplying of the gas-depletedreservoir fluid to a gas-depleted reservoir fluid-producing conductor;and

a sealed interface effector for co-operating with the wellbore stringfor establishing a sealed interface for preventing, or substantiallypreventing, bypassing of the diverter body-defined reservoir fluidconductor by the separated gas-depleted reservoir fluid.

wherein:

-   -   the flow diverter body, the sealed interface effector, and the        reservoir fluid-supplying conductor are co-operatively        configured such that, while the assembly is disposed within the        wellbore string, such that the sealed interface is defined, and        the reservoir fluid-supplying conductor is receiving reservoir        fluid from the downhole wellbore space that has been received        within the downhole wellbore space from the subterranean        formation:        -   the reservoir fluid is conducted to the diverter            body-defined reservoir fluid conductor via the reservoir            fluid-supplying conductor;        -   the reservoir fluid is conducted by the diverter            body-defined reservoir fluid conductor and discharged to a            reservoir fluid separation space of the uphole wellbore            space;        -   within the reservoir fluid separation space, a gas-depleted            reservoir fluid is separated from the discharged reservoir            fluid, in response to at least buoyancy forces; and        -   the separated gas-depleted reservoir fluid is conducted to            the diverter body-defined gas-depleted reservoir fluid            conductor, via the intermediate wellbore space, for            conduction to the surface via a gas-depleted reservoir fluid            producing conductor;    -   the reservoir fluid separation space defines a        separation-facilitating space portion of the intermediate        wellbore space;    -   and    -   the reservoir fluid-supplying conductor includes a contoured        section that is contoured with effect that, while a reservoir        fluid is being flowed through the reservoir fluid-supplying        conductor, a swirl in the reservoir fluid flow is induced.

In another aspect, there is provided a reservoir fluid conductionassembly for disposition within a wellbore that is extending into asubterranean formation, wherein the assembly includes:

a reservoir fluid-supplying conductor for conducting reservoir fluidthat is being received from the subterranean formation;

a gas separator, fluidly coupled to the reservoir fluid-supplyingconductor for receiving the reservoir fluid conducted by the reservoirfluid-supplying conductor, and effecting separation of gaseous materialfrom the reservoir fluid such that a gaseous-depleted reservoir fluid isobtained; and

wherein:

-   -   the gas separator and the reservoir fluid-supplying conductor        are co-operatively configured such that, while the assembly is        disposed within the wellbore, and the reservoir fluid-supplying        conductor is receiving reservoir fluid from the wellbore that        has been received within the wellbore from the subterranean        formation:        -   the reservoir fluid is conducted to the gas separator via            the reservoir fluid-supplying conductor; and        -   gaseous material is separated from the discharged reservoir            fluid by the separator such that a gas-depleted reservoir            fluid is obtained;

and

the reservoir fluid-supplying conductor includes a contoured sectionthat is contoured with effect that, while a reservoir fluid is beingflowed through the reservoir fluid-supplying conductor, a swirl in thereservoir fluid flow is induced.

In another aspect, there is provided a reservoir fluid conductionassembly, disposed within a wellbore, wherein the reservoir fluidconduction assembly comprises:

a reservoir fluid-supplying conductor for conducting reservoir fluidthat is being received from the subterranean formation;wherein:

the reservoir fluid-supplying conductor includes a contoured sectionthat is contoured with effect that, while a reservoir fluid is beingflowed through the reservoir fluid-supplying conductor, a swirl in thereservoir fluid flow is induced.

In another aspect, there is provided a reservoir fluid conductionassembly for disposition within a wellbore string, that is lining awellbore that is extending into a subterranean formation, such that anintermediate wellbore space is defined within a space that is disposedbetween the wellbore string and the assembly, wherein the assemblyincludes:

a reservoir fluid-supplying conductor, for conducting reservoir fluidthat is being received from a downhole wellbore space of the wellbore,and including a fluid conductor subassembly that includes:

-   -   a first tubing defining a conductor inlet;    -   a second tubing disposed within the first tubing such that an        intermediate subassembly space is defined between the first        tubing and the second tubing; and    -   a subassembly sealed interface disposed within the intermediate        subassembly space between the first tubing and the second        tubing;

a flow diverter body including (a) a diverter body-defined reservoirfluid conductor for conducting reservoir fluid, that is supplied fromthe reservoir fluid-supplying conductor, to a reservoir fluid separationspace of an uphole wellbore space of the wellbore, the uphole wellborespace being disposed uphole relative to the downhole wellbore space, and(b) a diverter body-defined gas-depleted reservoir fluid conductor forreceiving gas-depleted reservoir fluid and conducting the receivedgas-depleted reservoir fluid for effecting supplying of the gas-depletedreservoir fluid to a gas-depleted reservoir fluid-producing conductor;and

a sealed interface effector for co-operating with the wellbore stringfor establishing a sealed interface for preventing, or substantiallypreventing, bypassing of the diverter body-defined reservoir fluidconductor by the separated gas-depleted reservoir fluid;

wherein:

-   -   the flow diverter body, the sealed interface effector, and the        reservoir fluid-supplying conductor are co-operatively        configured such that, while the assembly is disposed within the        wellbore string, such that the sealed interface is defined, and        the reservoir fluid-supplying conductor is receiving reservoir        fluid from the downhole wellbore space that is being received        within the downhole wellbore space from the subterranean        formation:        -   reservoir fluid is conducted, via the reservoir            fluid-supplying conductor, including via the second tubing,            to the diverter body-defined reservoir fluid conductor;        -   while the conducting of the reservoir fluid is being            effected via the second tubing, the subassembly sealed            interface prevents, or substantially prevents, the reservoir            fluid, being conducted by the second tubing, from bypassing            the diverter body-defined reservoir fluid conductor;        -   the reservoir fluid is conducted by the diverter            body-defined reservoir fluid conductor and discharged to a            reservoir fluid separation space of the uphole wellbore            space;        -   within the reservoir fluid separation space, a gas-depleted            reservoir fluid is separated from the discharged reservoir            fluid, in response to at least buoyancy forces; and        -   the separated gas-depleted reservoir fluid is conducted to            the diverter body-defined gas-depleted reservoir fluid            conductor, via the intermediate wellbore space, for            conduction to the surface via a gas-depleted reservoir fluid            producing conductor;    -   the reservoir fluid separation space defines a        separation-facilitating space portion of the intermediate        wellbore space.

In another aspect, there is provided a reservoir fluid conductionassembly for disposition within a wellbore that is extending into asubterranean formation, wherein the assembly includes:

a reservoir fluid-supplying conductor, for conducting reservoir fluidthat is being received from the subterranean formation via the wellbore,and including a fluid conductor subassembly that includes:

-   -   a first tubing defining a conductor inlet;    -   a second tubing disposed within the first tubing such that an        intermediate subassembly space is defined between the first        tubing and the second tubing; and    -   a subassembly sealed interface disposed within the intermediate        subassembly space between the first and second tubing;

and

a gas separator, fluidly coupled to the reservoir fluid-supplyingconductor for receiving the reservoir fluid conducted by the reservoirfluid-supplying conductor, and effecting separation of gaseous materialfrom the reservoir fluid such that a gaseous-depleted reservoir fluid isobtained;

wherein:

-   -   the gas separator and the reservoir fluid-supplying conductor        are co-operatively configured such that, while the assembly is        disposed within the wellbore, and the reservoir fluid-supplying        conductor is receiving reservoir fluid from the wellbore that        has been received within the wellbore from the subterranean        formation:        -   the reservoir fluid is conducted, via the reservoir            fluid-supplying conductor, including via the second tubing,            to the separator;        -   while the conducting of the reservoir fluid is being            effected via the second tubing, the subassembly sealed            interface prevents, or substantially prevents, the reservoir            fluid, being conducted by the second tubing, from bypassing            the diverter body-defined reservoir fluid conductor; and        -   gaseous material are separated from the discharged reservoir            fluid by the separator such that gas-depleted reservoir            fluid is obtained.

In another aspect, there is provided a fluid production assemblycomprising a plurality of fluid conductor modules connected end to end,wherein each one of the fluid conductor modules, independently,includes:

a first tubing;a second tubing disposed within the first tubing such that anintermediate space is defined between the first tubing and the secondtubing; anda subassembly sealed interface disposed between the first tubing and thesecond tubing.

In another aspect, there is provided a fluid conductor modulecomprising:

a first tubing;a second tubing disposed within the first tubing such that anintermediate space is defined between the first tubing and the secondtubing; and a subassembly sealed interface disposed between the firsttubing and the second tubing.

BRIEF DESCRIPTION OF DRAWINGS

The preferred embodiments will now be described with reference to thefollowing accompanying drawings:

FIG. 1 is a schematic illustration of an embodiment of a systemincluding a reservoir fluid production assembly disposed within awellbore;

FIG. 2 is a schematic illustration of a an embodiment of a flow diverterof a reservoir fluid production assembly;

FIG. 3 is a schematic illustration of another embodiment of a systemincluding a reservoir fluid production assembly, similar to theembodiment in FIG. 1, and additionally including an anchor;

FIG. 4 is a schematic illustration of an anchor of the systemillustrated in FIG. 3;

FIG. 5 is a schematic illustration of another embodiment of a systemincluding a reservoir fluid production assembly disposed within awellbore, similar to the system illustrated in FIG. 1, and having areservoir fluid-supplying conductor who cross-sectional flow area isvariable along its central longitudinal axis;

FIG. 6 is a schematic illustration of another embodiment of a systemincluding a reservoir fluid production assembly disposed within awellbore, similar to the system illustrated in FIG. 1, and having areservoir fluid-supplying conductor including contoured portions;

FIG. 7A is a sectional side elevation view of a section of the reservoirfluid-supplying conductor of the system illustrated in FIG. 6; and

FIG. 7B is a sectional elevation view taken from one end of the sectionillustrated in FIG. 7A;

FIG. 8 is a schematic illustration of another embodiment of a systemincluding a reservoir fluid production assembly, similar to theembodiment in FIG. 1, and having a reservoir fluid-supplying conductorthat comprises fluid conductor modules;

FIG. 9 is a side elevation view of the combination of a fluid conductormodule and coupling that are integrated within the reservoirfluid-supplying conductor illustrated in FIG. 8;

FIG. 10 is sectional side elevation view of the combination of a fluidconductor module and coupling illustrated in FIG. 9, taken along linesA-A;

FIG. 11A is a side elevation view of an embodiment of a sealing ring forintegration into the fluid conductor module illustrated in FIG. 9;

FIG. 11B is a view from one end of the sealing ring illustrated in FIG.11A;

FIG. 11C is a sectional elevation view, taken along lines C-C in FIG.11B, of the sealing ring illustrated in FIG. 11A;

FIG. 12A is a side elevation view of another embodiment of a sealingring for integration into the fluid conductor module illustrated in FIG.9;

FIG. 12B is a view from one end of the sealing ring illustrated in FIG.12A;

FIG. 12C is a sectional elevation view, taken along lines A-A in FIG.12A, of the sealing ring illustrated in FIG. 12A;

FIG. 12D is a section view elevation view, taken along lines B-B in FIG.12C, of the sealing ring illustrated in FIG. 12A;

FIG. 13 is a side elevation view of another embodiment of a fluidconductor module that are integratable within the reservoirfluid-supplying conductor illustrated in FIG. 8;

FIG. 13A is sectional side elevation view of the fluid conductor moduleillustrated in FIG. 13A;

FIG. 13B is an enlarged view of detail “B” in FIG. 13A;

FIG. 13C is a front elevation view of a hanger of the fluid conductormodule illustrated in FIG. 13A;

FIG. 13D is a sectional side elevation of the hanger illustrated in FIG.13C taken along lines D-D;

FIG. 13E is a front elevation view of a spacer of the fluid conductormodule illustrated in FIG. 13A;

FIG. 13F is s side elevation of the spacer illustrated in FIG. 13E;

FIG. 13G is a front elevation view of a sealing member of the fluidconductor module illustrated in FIG. 13A;

FIG. 13H is a sectional side elevation of the sealing member illustratedin FIG. 13G taken along lines C-C;

FIG. 13J is a front elevation view of a sealing member retainer of thefluid conductor module illustrated in FIG. 13A;

FIG. 13K is a sectional side elevation of the sealing member retainerillustrated in FIG. 13J taken along lines E-E;

FIG. 13L is a front elevation view of a centralizer of the fluidconductor module illustrated in FIG. 13A; and

FIG. 13M is a side elevation of the centralizer illustrated in FIG. 13L.

DETAILED DESCRIPTION

As used herein, the terms “up”, “upward”, “upper”, or “uphole”, mean,relativistically, in closer proximity to the surface 106 and furtheraway from the bottom of the wellbore, when measured along thelongitudinal axis of the wellbore 102. The terms “down”, “downward”,“lower”, or “downhole” mean, relativistically, further away from thesurface 106 and in closer proximity to the bottom of the wellbore 102,when measured along the longitudinal axis of the wellbore 102.

Referring to FIGS. 1 and 2, there are provided systems 8, withassociated apparatuses, for producing hydrocarbons from a reservoir,such as an oil reservoir, within a subterranean formation 100, whenreservoir pressure within the oil reservoir is insufficient to conducthydrocarbons to the surface 106 through a wellbore 102.

The wellbore 102 can be straight, curved, or branched. The wellbore 102can have various wellbore portions. A wellbore portion is an axiallength of a wellbore 102. A wellbore portion can be characterized as“vertical” or “horizontal” even though the actual axial orientation canvary from true vertical or true horizontal, and even though the axialpath can tend to “corkscrew” or otherwise vary. The term “horizontal”,when used to describe a wellbore portion, refers to a horizontal orhighly deviated wellbore portion as understood in the art, such as, forexample, a wellbore portion having a longitudinal axis that is betweenabout 70 and about 110 degrees from vertical. The term “vertical”, whenused to describe a wellbore portion, refers to a vertical or highlydeviated vertical portion as understood in the art, such as, forexample, a wellbore portion having a longitudinal axis that is less thanabout 20 degrees from the vertical.

“Reservoir fluid” is fluid that is contained within an oil reservoir.Reservoir fluid may be liquid material, gaseous material, or a mixtureof liquid material and gaseous material. In some embodiments, forexample, the reservoir fluid includes water and hydrocarbons, such asoil, natural gas condensates, or any combination thereof.

Fluids may be injected into the oil reservoir through the wellbore toeffect stimulation of the reservoir fluid. For example, such fluidinjection is effected during hydraulic fracturing, water flooding, waterdisposal, gas floods, gas disposal (including carbon dioxidesequestration), steam-assisted gravity drainage (“SAGD”) or cyclic steamstimulation (“CSS”). In some embodiments, for example, the same wellboreis utilized for both stimulation and production operations, such as forhydraulically fractured formations or for formations subjected to CSS.In some embodiments, for example, different wellbores are used, such asfor formations subjected to SAGD, or formations subjected towaterflooding.

A wellbore string 113 is employed within the wellbore 102 forstabilizing the subterranean formation 100. In some embodiments, forexample, the wellbore string 113 also contributes to effecting fluidicisolation of one zone within the subterranean formation 100 from anotherzone within the subterranean formation 100.

The fluid productive portion of the wellbore 102 may be completed eitheras a cased-hole completion or an open-hole completion.

A cased-hole completion involves running wellbore casing down into thewellbore through the production zone. In this respect, in the cased-holecompletion, the wellbore string 113 includes wellbore casing.

The annular region between the deployed wellbore casing and the oilreservoir may be filled with cement for effecting zonal isolation (seebelow). The cement is disposed between the wellbore casing and the oilreservoir for the purpose of effecting isolation, or substantialisolation, of one or more zones of the oil reservoir from fluidsdisposed in another zone of the oil reservoir. Such fluids includereservoir fluid being produced from another zone of the oil reservoir(in some embodiments, for example, such reservoir fluid being flowedthrough a production tubing string disposed within and extending throughthe wellbore casing to the surface), or injected fluids such as water,gas (including carbon dioxide), or stimulations fluids such asfracturing fluid or acid. In this respect, in some embodiments, forexample, the cement is provided for effecting sealing, or substantialsealing, of flow communication between one or more zones of the oilreservoir and one or more others zones of the oil reservoir (forexample, such as a zone that is being produced). By effecting thesealing, or substantial sealing, of such flow communication, isolation,or substantial isolation, of one or more zones of the oil reservoir,from another subterranean zone (such as a producing formation), isachieved. Such isolation or substantial isolation is desirable, forexample, for mitigating contamination of a water table within the oilreservoir by the reservoir fluid (e.g. oil, gas, salt water, orcombinations thereof) being produced, or the above-described injectedfluids.

In some embodiments, for example, the cement is disposed as a sheathwithin an annular region between the wellbore casing and the oilreservoir. In some embodiments, for example, the cement is bonded toboth of the production casing and the oil reservoir.

In some embodiments, for example, the cement also provides one or moreof the following functions: (a) strengthens and reinforces thestructural integrity of the wellbore, (b) prevents, or substantiallyprevents, produced reservoir fluid of one zone from being diluted bywater from other zones. (c) mitigates corrosion of the wellbore casing,(d) at least contributes to the support of the wellbore casing, and e)allows for segmentation for stimulation and fluid inflow controlpurposes.

The cement is introduced to an annular region between the wellborecasing and the oil reservoir after the subject wellbore casing has beenrun into the wellbore. This operation is known as “cementing”.

In some embodiments, for example, the wellbore casing includes one ormore casing strings, each of which is positioned within the well bore,having one end extending from the well head. In some embodiments, forexample, each casing string is defined by jointed segments of pipe. Thejointed segments of pipe typically have threaded connections.

Typically, a wellbore contains multiple intervals of concentric casingstrings, successively deployed within the previously run casing. Withthe exception of a liner string, casing strings typically run back up tothe surface 106. Typically, casing string sizes are intentionallyminimized to minimize costs during well construction. Generally, smallercasing sizes make production and artificial lofting more challenging.

For wells that are used for producing reservoir fluid, few of theseactually produce through wellbore casing. This is because producingfluids can corrode steel or form undesirable deposits (for example,scales, asphaltenes or paraffin waxes) and the larger diameter can makeflow unstable. In this respect, a production string is usually installedinside the last casing string. The production string is provided toconduct reservoir fluid, received within the wellbore, to the wellhead116. In some embodiments, for example. the annular region between thelast casing string and the production tubing string may be sealed at thebottom by a packer.

To facilitate flow communication between the reservoir and the wellbore,the wellbore casing may be perforated, or otherwise include per-existingports (which may be selectively openable, such as, for example, byshifting a sleeve), to provide a fluid passage for enabling flow ofreservoir fluid from the reservoir to the wellbore.

In some embodiments, for example, the wellbore casing is set short oftotal depth. Hanging off from the bottom of the wellbore casing, with aliner hanger or packer, is a liner string. The liner string can be madefrom the same material as the casing string, but, unlike the casingstring, the liner string does not extend back to the wellhead 116.Cement may be provided within the annular region between the linerstring and the oil reservoir for effecting zonal isolation (see below),but is not in all cases. In some embodiments, for example, this liner isperforated to effect flow communication between the reservoir and thewellbore. In this respect, in some embodiments, for example, the linerstring can also be a screen or is slotted. In some embodiments, forexample, the production tubing string may be engaged or stung into theliner string, thereby providing a fluid passage for conducting theproduced reservoir fluid to the wellhead 116. In some embodiments, forexample, no cemented liner is installed, and this is called an open holecompletion or uncemented casing completion.

An open-hole completion is effected by drilling down to the top of theproducing formation, and then lining the wellbore (such as, for example,with a wellbore string 113). The wellbore is then drilled through theproducing formation, and the bottom of the wellbore is left open (i.e.uncased), to effect flow communication between the reservoir and thewellbore. Open-hole completion techniques include bare foot completions,pre-drilled and pre-slotted liners, and open-hole sand controltechniques such as stand-alone screens, open hole gravel packs and openhole expandable screens. Packers and casing can segment the open holeinto separate intervals and ported subs can be used to effect flowcommunication between the reservoir and the wellbore.

Referring to FIGS. 1 and 2, an assembly 10 is provided for effectingproduction of reservoir fluid from the reservoir 104 of the subterraneanformation 100.

In some embodiments, for example, a wellbore fluid conductor 113, suchas, for example, the wellbore string 113 (such as, for example, thecasing 113), is disposed within the wellbore 102. The assembly 10 isconfigured for disposition within the wellbore fluid conductor 113, suchthat an intermediate wellbore passage 112 is defined within the wellborefluid conductor 113, between the assembly 10 and the wellbore fluidconductor 113. In some embodiments, for example, the intermediatewellbore passage 112 is an annular space disposed between the assembly10 and the wellbore string 113. In some embodiments, for example, theintermediate wellbore passage 112 is defined by the space that extendsoutwardly, relative to the central longitudinal axis of the assembly 10,from the assembly 10 to the wellbore fluid conductor 113. In someembodiments, for example, the intermediate wellbore passage 112 extendslongitudinally to the wellhead 116, between the assembly 10 and thewellbore string 113.

The assembly 10 includes a production string 202 that is disposed withinthe wellbore 102. The production string 202 includes a pump 300

The pump 300 is provided to, through mechanical action, pressurize andeffect conduction of the reservoir fluid from the reservoir 104, throughthe wellbore 102, and to the surface 106, and thereby effect productionof the reservoir fluid. It is understood that the reservoir fluid beingconducted uphole through the wellbore 102, via the production string202, may be additionally energized by supplemental means, including bygas-lift. In some embodiments, for example, the pump 300 is a sucker rodpump. Other suitable pumps 300 include screw pumps, electricalsubmersible pumps, and jet pumps.

The system also includes a flow diverter 600. The flow diverter 600 isprovided for, amongst other things, mitigating gas lock within the pump300. In some embodiments, for example, the flow diverter 600 is disposedwithin a vertical portion of the wellbore 102 that extends to thesurface 106.

In some embodiments, the flow diverter 600 includes a wellbore stringcounterpart 600B and an assembly counterpart 600C. The wellbore string113 defines the wellbore string counterpart 600B, and the assembly 10defines the assembly counterpart 600C. The flow diverter 600 defines:(i) a reservoir fluid-conducting passage 6002 for diverted reservoirfluid, received within the downhole wellbore space from the reservoir104, to a reservoir fluid separation space 112X of the wellbore 102,with effect that a gas-depleted reservoir fluid is separated from thereservoir fluid within the reservoir fluid separation space 112X inresponse to at least buoyancy forces; and (ii) a gas-depleted reservoirfluid-conducting passage 6004 for receiving the separated gas-depletedreservoir fluid while the separated gas-depleted reservoir fluid isflowing in a downhole direction, and diverting the flow of the receivedgas-depleted reservoir fluid such that the received gas-depletedreservoir fluid is conducted by the flow diverter 600 in the upholedirection to the pump 300.

As discussed above, the wellbore 102 is disposed in flow communication(such as through perforations provided within the installed casing orliner, or by virtue of the open hole configuration of the completion),or is selectively disposable into flow communication (such as byperforating the installed casing, or by actuating a valve to effectopening of a port), with the reservoir 104. When disposed in flowcommunication with the reservoir 104, the wellbore 102 is disposed forreceiving reservoir fluid flow from the reservoir 104.

The production string inlet 204 is for receiving, via the wellbore, thereservoir fluid flow from the reservoir. In this respect, the reservoirfluid flow enters the wellbore 102, as described above, and is thenconducted to the production string inlet 204. The production string 202includes a reservoir fluid-supplying conductor 206, disposed downholerelative to the flow diverter 600 for conducting the reservoir fluid(such as a reservoir fluid flow), that is being received by theproduction string inlet, such that the reservoir fluid, that is receivedby the inlet 204, is conducted to the flow diverter 600 via thefluid-supplying conductor 206. The production string 202 also includes agas-depleted reservoir fluid-producing conductor 210, disposed upholerelative to the flow diverter 600 for conducting a gas-depletedreservoir fluid (such as a gas-depleted reservoir fluid flow) from theflow diverter 600 to a production string outlet 208, located at thewellhead 116.

It is preferable to remove at least a fraction of the gaseous materialfrom the reservoir fluid flow being conducted within the productionstring 202, prior to the pump suction 302, in order to mitigate gasinterference or gas lock conditions during pump operation. The flowdiverter 600, is provided to, amongst other things, perform thisfunction. In this respect, the flow diverter 600 is disposed downholerelative to the pump 300 and is fluidly coupled to the pump suction 302,such as, for example, by an intermediate fluid conductor that forms partof the fluid-producing conductor 210, such as piping. Suitable exemplaryflow diverters are described in International Application No.PCT/CA2015/000178, published on Oct. 1, 2015.

In some embodiments, for example, the assembly counterpart 600C includesa fluid diverter body 600A.

In some embodiments, for example, the flow diverter body 600A isconfigured such that the depletion of gaseous material from thereservoir fluid material, that is effected while the assembly 10 isdisposed within the wellbore 102, is effected externally of the flowdiverter body 600A within the wellbore 102, such as, for example, withinan uphole wellbore space 108 of the wellbore 102.

The flow diverter body 600A includes a reservoir fluid receiver 602 forreceiving the reservoir fluid (such as, for example, in the form of areservoir fluid flow) that is being conducted (e.g. flowed), via thefluid-supplying conductor 206 of the production string 202, from theproduction string inlet 204. In some embodiments, for example, thefluid-supplying conductor 206 extends from the inlet 204 to the receiver602. In this respect, the fluid-supplying conductor 206 is fluidlycoupled to the inlet 204.

The flow diverter body 600A also includes a reservoir fluid dischargecommunicator 604 that is fluidly coupled to the reservoir fluid receiver602 via a reservoir fluid-conductor 603. In this respect, the reservoirfluid conductor 603 defines at least a portion of the reservoirfluid-conducting passage 6002.

The reservoir fluid conductor 603 defines one or more reservoir fluidconductor passages 603A. In some of the embodiments described below, forexample, the one or more reservoir fluid-conducting passages 603A. Thereservoir fluid discharge communicator 604 is configured for dischargingreservoir fluid (such as, for example, in the form of a flow) that isreceived by the reservoir fluid receiver 602 and conducted to thereservoir fluid discharge communicator 604 via the reservoir fluidconductor 603. In some embodiments, for example, the reservoir fluiddischarge communicator 604 is disposed at an opposite end of the flowdiverter body 600A relative to the reservoir fluid receiver 602.

The flow diverter body 600A also includes a gas-depleted reservoir fluidreceiver 608 for receiving a gas-depleted reservoir fluid (such as, forexample, in the form of a flow), after gaseous material has beenseparated from the reservoir fluid (for example, a reservoir fluidflow), that has been discharged from the reservoir fluid dischargecommunicator 604, in response to at least buoyancy forces. In thisrespect, the gas-depleted reservoir fluid receiver 608 and the reservoirfluid discharge communicator 604 are co-operatively configured such thatthe gas-depleted reservoir fluid receiver 608 is disposed for receivinga gas-depleted reservoir fluid flow, after gaseous material has beenseparated from the received reservoir fluid flow that has beendischarged from the reservoir fluid discharge communicator 604, inresponse to at least buoyancy forces. In some embodiments, for example,the reservoir fluid discharge communicator 604 is disposed at anopposite end of the flow diverter body 600A relative to the gas-depletedreservoir fluid receiver 608.

The flow diverter body 600A also includes a gas-depleted reservoir fluidconductor 610 that defines a gas-depleted reservoir fluid-conductingpassage 610A configured for conducting the gas-depleted reservoir fluid(for example, a gas-depleted reservoir fluid flow), received by thereceiver 608, to the gas-depleted reservoir fluid discharge communicator604. In some embodiments, for example, the gas-depleted reservoir fluiddischarge communicator 611 is disposed at an opposite end of the flowdiverter body 600A relative to the gas-depleted reservoir fluid receiver608. The gas-depleted reservoir fluid discharge communicator 611 isconfigured for fluid coupling to the pump 300, wherein the fluidcoupling is for supplying the pump 300 with the gas-depleted reservoirfluid received by the receiver 610 and conducted through at least thegas-depleted reservoir fluid conductor 610. In this respect, thegas-depleted reservoir fluid-conducting passage 610A defines at least aportion of the gas-depleted reservoir fluid-conducting passage 6004.

Referring to FIG. 2, in some embodiments, for example, the reservoirfluid discharge communicator 604 is oriented such that, a ray (see, forexample ray 604A), that is disposed along the central longitudinal axisof the reservoir fluid discharge communicator, is disposed in an upholedirection at an acute angle of less than 30 degrees relative to thecentral longitudinal axis of the wellbore portion within which the flowdiverter body 600A is disposed.

Again referring to FIG. 2, in some embodiments, for example, thereservoir fluid discharge communicator 604 is oriented such that, a ray(see, for example ray 604A), that is disposed along the centrallongitudinal axis of the reservoir fluid discharge communicator 604, isdisposed in an uphole direction at an acute angle of less than 30degrees relative to the vertical (which includes disposition of the ray604A along a vertical axis).

In some embodiments, for example, the flow diverter body 600A includesthe reservoir fluid receiver 602 (such as, for example, in the form ofone or more ports), the reservoir fluid discharge communicator 604 (suchas, for example, in the form of one or more ports), and the reservoirfluid conductor 603 (such as, for example, in the form of one or morefluid passages 603A, such as, for example, a network of fluid) forfluidly coupling the receiver 602 and the discharge communicator 604.The flow diverter body 600A also includes the gas-depleted reservoirfluid receiver 608 (such as, for example, in the form of one or moreports), gas-depleted reservoir fluid discharge communicator 611 (suchas, for example, in the form of one or more ports), and the gas-depletedreservoir fluid conductor 610 (such as, for example, in the form of afluid passage or a network of fluid passages) for fluidly coupling thereceiver 608 to the discharge communicator 611.

The assembly counterpart 600C also includes a wellbore sealed interfaceeffector 400 configured for interacting with a wellbore feature fordefining a wellbore sealed interface 500 within the wellbore 102,between: (a) an uphole wellbore space 108 of the wellbore 102, and (b) adownhole wellbore space 110 of the wellbore 102, while the assembly 10is disposed within the wellbore 102.

In some embodiments, for example, the disposition of the sealedinterface 500 is such that flow communication, via the intermediatewellbore passage 112, between an uphole wellbore space 108 and adownhole wellbore space 110 (and across the sealed interface 500), isprevented, or substantially prevented. In some embodiments, for example,the disposition of the sealed interface 500 is such that fluid flow,across the sealed interface 500, in a downhole direction, from theuphole wellbore space 108 to the downhole wellbore space 110, isprevented, or substantially prevented.

In such embodiments, for example, the disposition of the sealedinterface 500 is effected by the combination of at least: (i) a sealed,or substantially sealed, disposition of the wellbore string 113 relativeto a polished bore receptacle 114 (such as that effected by a packer240A disposed between the wellbore string 113 and the polished borereceptacle 114), and (ii) a sealed, or substantially sealed, dispositionof the fluid-supplying conductor 206 relative to the polished borereceptacle 114. In this respect, the sealed interface 500 functions toprevent, or substantially prevented, reservoir fluid flow, that isreceived within the wellbore 102 (that is lined with the wellbore string113), from bypassing the reservoir fluid receiver 602, and, as acorollary, the reservoir fluid is directed to the reservoir fluidreceiver 602 for receiving by the reservoir fluid receiver 602. As well,the sealed interface 500 functions to prevent, or substantiallyprevented, gas-depleted reservoir fluid flow, that has been separatedfrom the reservoir fluid discharged into the wellbore 102 from thedischarge communicator 604, from bypassing the gas-depleted reservoirfluid receiver 608 and, as a corollary, the gas-depleted reservoir fluidis directed to the gas-depleted reservoir fluid receiver 608 forreceiving by the gas-depleted reservoir fluid receiver 608.

In some embodiments, for example, the sealed, or substantially sealed,disposition of the fluid-supplying conductor 206 relative to thepolished bore receptacle 114 is effected by a latch seal assembly. Asuitable latch seal assembly is a Weatherford™ Thread-Latch Anchor SealAssembly™.

In some embodiments, for example, the sealed, or substantially sealed,disposition of the downhole fluid-supplying conductor 206 relative tothe polished bore receptacle 114 is effected by one or more o-rings orseal-type Chevron rings. In this respect, the sealing interface effector400 includes the o-rings, or includes the seal-type Chevron rings.

In some embodiments, for example, the sealed, or substantially sealed,disposition of the fluid-supplying conductor 206 relative to thepolished bore receptacle 114 is disposed in an interference fit with thepolished bore receptacle. In some of these embodiments, for example, thefluid-supplying conductor 206 is landed or engaged or “stung” within thepolished bore receptacle 114.

The above-described disposition of the wellbore sealed interface 500provide for conditions which minimize solid debris accumulation in thejoint between the downhole fluid-supplying conductor 206 and thepolished bore receptacle 114 or in the joint between the polished borereceptacle 114 and the wellbore string 113. By providing for conditionswhich minimize solid debris accumulation within the joint, interferenceto movement of the separator relative to the liner, or the casing, asthe case may be, which could be effected by accumulated solid debris, ismitigated.

Referring to FIG. 1, in some embodiments, for example, the sealedinterface 500 is disposed within a section of the wellbore 102 whoseaxis 14A is disposed at an angle “a” of at least 60 degrees relative tothe vertical “V”. In some of these embodiments, for example, the sealedinterface 500 is disposed within a section of the wellbore whose axis isdisposed at an angle “a” of at least 85 degrees relative to the vertical“V”. In this respect, disposing the sealed interface 500 within awellbore section having such wellbore inclinations minimizes soliddebris accumulation at the sealed interface 500.

In some embodiments, for example, the flow diverter body 600, the sealedinterface effector 400, and the reservoir fluid conductor 206, areco-operatively configured such that, while the assembly 10 is disposedwithin the wellbore string 113 such that the sealed interface 500 isdefined, and the reservoir fluid-supplying conductor 206 is receivingreservoir fluid from the downhole wellbore space 110 that has beenreceived within the downhole wellbore space 110 from the subterraneanformation 100:

the reservoir fluid is conducted to the reservoir fluid receiver 602 viathe reservoir fluid-supplying conductor 206;

the reservoir fluid is conducted to the reservoir fluid dischargecommunicator 604 by the reservoir fluid conductor 603 and discharged tothe reservoir fluid separation space 112X of the uphole wellbore space108;

within the reservoir fluid separation space 112X, a gas-depletedreservoir fluid is separated from the discharged reservoir fluid, inresponse to at least buoyancy forces, such that the gas-depletedreservoir fluid is obtained;

the separated gas-depleted reservoir fluid is conducted to thegas-depleted reservoir fluid receiver 608 via the intermediate wellborepassage 112, and the received gas-depleted reservoir fluid is conductedfrom the gas-depleted reservoir fluid receiver 608 to the pump 300 viaat least the conductor 610 and the gas-depleted reservoir fluiddischarge communicator 611.

In this respect, in such embodiments, for example, at least a portion ofthe space within the intermediate wellbore space 112, between thereservoir fluid discharge communicator 604 and the gas-depletedreservoir fluid receiver 608, defines at least a portion of thegas-depleted reservoir fluid-conducting passage 6004.

Once received by the pump 300, the gas-depleted reservoir fluid ispressurized by the pump 300 and conducted to the surface via thereservoir fluid-producing conductor 210.

Also, the separation of gaseous material from the reservoir fluid iswith effect that a liquid-depleted reservoir fluid is obtained and isconducted uphole (in the gaseous phase, or at least primarily in thegaseous phase with relatively small amounts of entrained liquid) via theintermediate wellbore passage 112 that is disposed between the assembly10 and the wellbore string 113 (see above).

The reservoir fluid produced from the subterranean formation 100, viathe wellbore 102, including the gas-depleted reservoir fluid, theliquid-depleted reservoir material, or both, may be discharged throughthe wellhead 116 to a collection facility, such as a storage tank withina battery.

In some embodiments, for example, the flow diverter body 600A isconfigured such that the gas-depleted reservoir fluid receiver 608 isdisposed downhole relative to (such as, for example, vertically below)the reservoir fluid discharge communicator 604, with effect that theseparated gas-depleted reservoir fluid is conducted in a downholedirection to the gas-depleted reservoir fluid receiver 608.

In some embodiments, for example, separation of gaseous material, fromthe reservoir fluid that is being discharged from the reservoir fluiddischarge communicator 604, is effected within an uphole-disposed space1121X of the intermediate wellbore passage 112, the uphole-disposedspace 1121X being disposed uphole relative to the reservoir fluiddischarge communicator 604. In this respect, in some embodiments, forexample, the reservoir fluid separation space 112X includes theuphole-disposed space 1121X.

In some embodiments, for example, a flow diverter body-definedintermediate wellbore passage portion 1121Y of the intermediate wellborepassage 112 is disposed within a space between the flow diverter body600A and the wellbore string 113, and effects flow communication betweenthe reservoir fluid discharge communicator 604 and the gas-depletedreservoir fluid receiver 608 for effecting conducting of thegas-depleted reservoir fluid to the gas-depleted reservoir fluidreceiver 608. In this respect, in such embodiments, for example, theflow diverter body-defined intermediate wellbore passage portion 1121Ydefines at least a portion of the gas-depleted reservoirfluid-conducting passage 6004.

In some embodiments, for example, the space between the flow diverterbody 600A and the wellbore string 113, within which the flow diverterbody-defined intermediate wellbore passage portion 1121Y is disposed, isan annular space. In some embodiments, for example, the flow diverterbody-defined intermediate space 1121Y is defined by the entirety, or thesubstantial entirety, of the space between the flow diverter body 600Aand the wellbore string 113. In some embodiments, for example,separation of gaseous material, from the reservoir fluid that isdischarged from the reservoir fluid discharge communicator 604, iseffected within the flow diverter body-defined intermediate wellborepassage portion 1121Y. In this respect, in some embodiments, forexample, at least a portion of the reservoir fluid separation space 112Xis co-located with at least a portion of the flow diverter body-definedintermediate wellbore passage portion 1121Y.

In some embodiments, for example, the separation of gaseous material,from the reservoir fluid that is being discharged from the reservoirfluid discharge communicator 604, is effected within both of theuphole-disposed space 1121X and the flow diverter body-definedintermediate wellbore passage portion 1121Y. In this respect, in someembodiments, for example, the reservoir fluid is discharged from thereservoir fluid discharge communicator 604 into the uphole wellborespace 1121X, and, in response to at least buoyancy forces, the gaseousmaterial is separated from the discharged reservoir fluid, while thereservoir fluid is being conducted downhole, from the uphole-disposedspace 1121X, through the flow diverter body-defined intermediatewellbore passage portion 1121Y, and to the gas-depleted reservoir fluidreceiver 608. In this respect, in some embodiments, for example, theuphole-disposed space 1121X is merged with the flow diverterbody-defined intermediate wellbore passage portion 1121Y

In some embodiments, for example, the reservoir fluid separation space112X spans a continuous space extending from the assembly to thewellbore string 113, and the continuous space extends outwardly relativeto the central longitudinal axis of the assembly 10.

In some embodiments, for example, the reservoir fluid separation space112X spans a continuous space extending from the assembly to thewellbore string 113, and the continuous space extends outwardly relativeto the central longitudinal axis of the wellbore 102.

In some embodiments, for example, the reservoir fluid separation space112X is disposed within a vertical portion of the wellbore 102 thatextends to the surface 106.

In some embodiments, for example, the ratio of the minimumcross-sectional flow area of the reservoir fluid separation space 112Xto the maximum cross-sectional flow area of the fluid passage 206Adefined by the reservoir fluid-supplying conductor 206 is at least about1.5.

In some embodiments, for example, the space, between: (a) thegas-depleted reservoir fluid receiver 608 of the flow diverter body600A, and (b) the sealed interface 500, defines a sump 700 forcollection of solid particulate that is entrained within fluid beingdischarged from the reservoir fluid discharge communicator 604 of theflow diverter body 600A, and the sump 700 has a volume of at least 0.1m³. In some embodiments, for example, the volume is at least 0.5 m³. Insome embodiments, for example, the volume is at least 1.0 m³. In someembodiments, for example, the volume is at least 3.0 m³.

By providing for the sump 700 having the above-described volumetricspace characteristic, and/or the above-described minimum separationdistance characteristic, a suitable space is provided for collectingrelative large volumes of solid debris, from the gas-depleted reservoirfluid being flowed downwardly to the gas-depleted reservoir fluidreceiver 608, such that interference by the accumulated solid debriswith the production of oil through the system is mitigated. Thisincreases the run-time of the system before any maintenance is required.As well, because the solid debris is deposited over a larger area, thepropensity for the collected solid debris to interfere with movement ofthe flow diverter body 600A within the wellbore 102, such as duringmaintenance (for example, a workover) is reduced.

As above-described, the reservoir fluid-producing conductor 210 extendsfrom the gas-depleted reservoir fluid discharge communicator 611 to thewellhead 116 for effecting flow communication between the dischargecommunicator 611 and the earth's surface 106, such as, for example, acollection facility located at the earth's surface 106, and defines afluid passage 210A. In some embodiments, for example, reservoirfluid-supplying conductor 206 defines a fluid passage 206A. Thecross-sectional flow area of the fluid passage 210A is greater than thecross-sectional flow area of the fluid passage 206A. In someembodiments, for example, the ratio of the cross-sectional flow area ofthe fluid passage 210A to the cross-sectional flow area of the fluidpassage 206A is at least 1.1, such as, for example, at least 1.25, suchas, for example, at least 1.5.

In some embodiments, for example, the reservoir fluid-supplyingconductor 206 includes a velocity string 207, and, in some embodiments,for example, the entirety, or the substantial entirety of the reservoirfluid-supplying conductor 206 is a velocity string 207. In someembodiments, for example, the velocity string 207 extends from theproduction string inlet 204. In some embodiments, for example, at least25% of the length of the fluid-supplying conductor 206, as measuredalong the central longitudinal axis of the fluid-supplying conductor206, is a velocity string 207. In some embodiments, for example, thelength of the velocity string 207, measured along the centrallongitudinal axis of the velocity string, is at least 20 feet. In someembodiments, for example, the velocity string 207 includes a fluidpassage 207A, and the cross-sectional area of the entirety of the fluidpassage 207A is less than the cross-sectional area of the entirety ofthe fluid passage 210A of the fluid-producing conductor 210. In thisrespect, in some embodiments, for example, the maximum cross-sectionalarea of the fluid passage 207A is less than the minimum cross-sectionalarea of the fluid passage 210A. In some embodiments, for example, themaximum cross-sectional area of the fluid passage 207A is less thanabout 75% (such as, for example 50%) of the minimum cross-sectional areaof at least 75% (such as, for example, at least 80%, such as, forexample, at least 85%, such as, for example, at least 90%, such as, forexample, at least 95%) of the length of the fluid-supplying conductor206, as measured along the central longitudinal axis of thefluid-supplying conductor 206. In some embodiments, for example, thelength of the fluid-supplying conductor 206, as measured along thecentral longitudinal axis of the fluid-supplying conductor 206, is atleast 500 feet, such as, for example, at least 750 feet, such as, forexample at least 1000 feet.

In some embodiments, for example, the flow diverter 600 is disposeduphole of a horizontal section 102C of the wellbore 102, such as, insome embodiments, for example, within a vertical section 102A, or, insome embodiments, for example, within a transition section 102B.

In some embodiments, for example, the central longitudinal axis of thepassage 102CC of the horizontal section 102C is disposed along an axisthat is between about 70 and about 110 degrees relative to the vertical“V”, the central longitudinal axis of the passage 102AA of the verticalsection 102A is disposed along an axis that is less than about 20degrees from the vertical “V”, and the transition section 102B isdisposed between the sections 102A and 102C. In some embodiments, forexample, the transition section 102B joins the sections 102A and 102C.In some embodiments, for example, the vertical section 102A extends fromthe transition section 102B to the surface 106.

In some of these embodiments, for example, the reservoir fluid-supplyingconductor 206 extends from the flow diverter 600, in a downholedirection, into the horizontal section 102C, such that the inlet 204 isdisposed within the horizontal section 102C.

Referring to FIGS. 3 and 4, an anchor 620 is mounted to the flowdiverter 600 for effecting coupling (such as, for example, anchoring) ofthe assembly 10 to the wellbore string. In some embodiments, forexample, the anchor 620 is an industry standard tubing anchor.

In some embodiments, for example, the anchor 620 is disposed such thatthere is an absence, or substantial absence, of opposition to flow of agaseous material, that has been separated from the reservoir fluidwithin the reservoir fluid separation space 112X in response to at leastbuoyancy forces, by the anchor 620.

In some embodiments, for example, the anchor 620 is disposed such thatfluid communication, via one or more flowpaths 112A defined between theanchor 620 and the wellbore fluid conductor 114 (see FIG. 3) is definedbetween the reservoir fluid discharge communicator 604 and thegas-depleted reservoir fluid inlet port 608.

Reservoir fluid that is being conducted through the transition section102B is particularly susceptible to liquid loading because of the changein direction, to the reservoir fluid being conducted through thetransition section 102B, that is urged by virtue of the configuration oftransition section 102B. To mitigate liquid loading, the reservoirfluid-supplying conductor 206 is configured such that the reservoirfluid is being conducted through the transition section 102B at asufficiently high speed. In this respect, and referring to FIG. 5, thereservoir fluid-supplying conductor 206 includes a verticalsection-disposed portion 2061, that is disposed in the vertical section102A, a transition section-disposed portion 2062, that is disposed inthe transition section 102B, and a horizontal-section disposed portion2063, that is disposed in the horizontal section 102C, A cross-sectionalarea of the fluid passage 2062A of the transition section-disposedportion 2062 is less than both of: (i) a cross-sectional area of thefluid passage 2061A of the vertical section-disposed portion 2061, and(ii) a cross-sectional area of the fluid passage 2063A of the horizontalsection-disposed portion 2063. In some embodiments, for example, thecentral longitudinal axis of the fluid passage 2063A of the horizontalsection-disposed portion 2063 is disposed along an axis that is betweenabout 70 and about 110 degrees relative to the vertical “V”, the centrallongitudinal axis of the fluid passage 2063A of the verticalsection-disposed portion 2063 is disposed along an axis that is lessthan about 20 degrees from the vertical “V”, and the transition-sectiondisposed portion 2062 is disposed between the portions 2061 and 2063. Insome embodiments, for example, the transition-section disposed portion2062 joins the portions 2061 and 2063. In some embodiments, for example,the vertical section-disposed portion 2061 extends from the transitionsection-disposed portion 2062 to the surface 106.

In some embodiments, for example, the ratio of the minimumcross-sectional area of the fluid passage 2063A of the horizontalsection-disposed portion 2063 to the maximum cross-sectional area of thefluid passage 2062A of the transition section-disposed portion 2062 isat least 1.1, such as, for example, at least 1.2, such as, for exampleat least 1.25. In some embodiments, for example, the ratio of theminimum cross-sectional area of the fluid passage 2061A of the verticalsection-disposed portion 2061 to the maximum cross-sectional area of thefluid passage 2062A of the transition section-disposed portion 2062 isat least 1.1, such as, for example, at least 1.2, such as, for exampleat least 1.25. In some embodiments, for example, the ratio of theminimum cross-sectional area of the fluid passage 2063A of thehorizontal section-disposed portion 2063 to the maximum cross-sectionalarea of the fluid passage 2062A of the transition section-disposedportion 2062 is at least 1.1, such as, for example, at least 1.2, suchas, for example at least 1.25, and also the ratio of the minimumcross-sectional area of the fluid passage 2061A of the verticalsection-disposed-portion 2061 to the maximum cross-sectional area of thefluid passage 2062A of the transition section disposed portion 2062 isat least 1.1, such as, for example, at least 1.2, such as, for exampleat least 1.25.

In some embodiments, for example, the transition section-disposedportion 2062 extends along a curved path. In some embodiments, forexample, the length of the transition section-disposed portion 2062, asmeasured along the central longitudinal axis of the section-disposedportion 2062, is at least 50 feet, such as, for example, at least 100feet, such as, for example, at least 200 feet, such as, for example, atleast 300 feet, such as, for example, at least 400 feet, such as, forexample, at least 500 feet.

In some embodiments, for example, the vertical section-disposed portion2061 includes an operative vertical section-disposed portion and theoperative vertical section-disposed portion has a length, measured alongthe central longitudinal axis of the fluid passage 2061A of the verticalsection-disposed portion 2061, that is at least 50% (such as, forexample, at least 75%, such as, for example, 100%) of the length of thevertical section-disposed portion 2061 measured along the centrallongitudinal axis of the fluid passage 2061A of the verticalsection-disposed portion 2061, the transition section-disposed portion2062 includes an operative transition section-disposed portion and theoperative transition section-disposed portion has a length, measuredalong the central longitudinal axis of the fluid passage 2062A of thetransition section-disposed portion 2062, that is at least 50% (such as,for example, at least 75%, such as, for example, 100%) of the length ofthe transition section-disposed portion 2062 measured along the centrallongitudinal axis of the fluid passage 2062A of the transitionsection-disposed portion 2062, and the horizontal section-disposedportion 2061 includes an operative horizontal section-disposed portionand the operative horizontal section-disposed portion has a length,measured along the central longitudinal axis of the fluid passage 2061Cof the horizontal section-disposed portion 2061C, that is at least 50%(such as, for example, at least 75%, such as, for example, 100%) of thelength of the horizontal section-disposed portion 2061 measured alongthe central longitudinal axis of the fluid passage 2061A of thehorizontal section-disposed portion 2061, and the ratio of the minimumcross-sectional area of the fluid passage 2061A of the operativehorizontal section-disposed portion 2061 to the maximum cross-sectionalarea of the fluid passage 2062A of the operative transitionsection-disposed portion is at least 1.1, such as, for example, at least1.2, such as, for example at least 1.25. In some embodiments, forexample, the ratio of the minimum cross-sectional area of the fluidpassage 2061A of the operative vertical section-disposed portion to themaximum cross-sectional area of the fluid passage 2062A of the operativetransition section disposed portion is at least 1.1, such as, forexample, at least 1.2, such as, for example at least 1.25. In someembodiments, for example, the ratio of the minimum cross-sectional areaof the fluid passage 2063A of the operative horizontal section-disposedportion to the maximum cross-sectional area of the fluid passage 2062Aof the operative transition section disposed portion is at least 1.1,such as, for example, at least 1.2, such as, for example at least 1.25,and also the ratio of the minimum cross-sectional area of the fluidpassage 2061A of the operative vertical section-disposed portion to themaximum cross-sectional area of the fluid passage 2062A of thetransition section-disposed portion is at least 1.1, such as, forexample, at least 1.2, such as, for example at least 1.25. In someembodiments, for example, the operative transition section-disposedportion extends along a curved path.

Referring to FIGS. 6, 7A, and 7B, the reservoir fluid-supplyingconductor 206 includes an internal surface 206B that defines the fluidpassage 206A for conducting the reservoir fluid that is received by theinlet 204. In some embodiments, for example, the internal surface 206Bis that of the velocity string 207 such that the fluid passage 206A isdefined by the fluid passage 207A.

In some embodiments, for example, the internal surface 206B of at leasta section of the reservoir fluid-supplying conductor 206 is contouredwith effect that reservoir fluid being conducted through the fluidpassage 206A has a swirl flow component.

In some embodiments, for example, the internal surface 206B of at leasta section of the reservoir fluid-supplying conductor 206 is contouredwith effect that, while a reservoir fluid is being flowed through thefluid passage 206A, a swirl in the flow is induced.

In some embodiments, for example, the internal surface 206B of at leasta section of the reservoir fluid-supplying conductor 206 is contouredfor generating a swirl flow in reservoir fluid being conducted throughthe fluid passage 206A.

In some embodiments, for example, the swirl is disposed about thecentral longitudinal axis of the fluid passage 206A.

In some embodiments, for example, the contouring is defined by a rifledgroove 206C, such as, for example, a helical rifled groove. In someembodiments, for example, the rifled groove has a minimum depth of atleast 0.1 cm. In some embodiments, for example, the pitch of the rifledgroove is between 30 degrees to 60 degrees, such as, for example,between 40 degrees and 55 degrees.

In some embodiments, for example, the contouring is defined by aplurality of spaced apart vanes extending into the fluid passage 206A.

In some embodiments, for example, the at least a section of thereservoir fluid-supplying conductor 206 (i.e. the “contoured portionsection 206C”), whose internal surface 206B is contoured in any one ofthe configuration described above, defines at least 10% (such as, forexample, at least 25%, such as, for example, at least 50%) of the totallength of the fluid passage 206A as measured along the centrallongitudinal axis 2060D of the fluid passage 206A. In some embodiments,for example, the contoured portion section 206C has a length of at least10 feet, as measured along the central longitudinal axis of the fluidpassage 206A. In some embodiments, for example, the contoured portionsection 206C has a length of at least 25 feet, as measured along thecentral longitudinal axis of the fluid passage 206A. In someembodiments, for example, the contoured portion section 206C has alength of at least 50 feet as measured along the central longitudinalaxis of the fluid passage 206A. In some embodiments, for example, thecontoured portion section 206C has a length of at least 100 feet asmeasured along the central longitudinal axis of the fluid passage 206A.

It is desirable to avoid slug flow through the reservoir fluid-supplyingconductor 206, as this results in liquid loading. Liquid loading reducesrecovery from the well. By enabling swirl flow, slug flow through thereservoir fluid-supplying conductor 206 is suppressed.

In some embodiments, for example, the internal surface 206B of thecontoured portion section 206D is defined by a polymeric material liner,such that the contoured portion section 206D is lined with polymericmaterial, and such that the contoured portion section 206D is defined bya polymeric material-lined fluid conductor. By integrating the polymericmaterial liner, standard tubing (configured according to specificationsthe American Petroleum Institute (“API”)) can be used for the conductor206, and the cross-sectional flow of the standard tubing is attenuatedby the liner to facilitate flow of the reservoir fluid at a desiredspeed. In this respect, in some embodiments, for example, the contouringis of the polymeric material liner. In some embodiments, for example,the polymeric material includes plastic material.

In some embodiments, for example, the reservoir fluid-supplyingconductor 206 includes two or more spaced-apart contoured portionsections 206D. The contoured portion sections 206D are co-operativelydisposed such that a desired swirl flow condition is effectible withinthe fluid passage 206A.

Referring to FIGS. 8, 9, 10, 11A, 11B, 11C, 12A, 12B, 12C, and 12D, insome embodiments, for example, the reservoir fluid supplying conductor206 includes a fluid conductor module 220. In some embodiments, forexample, the reservoir fluid supplying conductor 206 includes aplurality of fluid conductor modules 220, and each one of the modules220, independently, has a configuration of the fluid conductor 220. Insome embodiments, for example, the modules 220 are connected end-to-end.In some embodiments, for example, at least some of the modules 220 arespaced apart from one another. Each one of the modules, independently,functions as a fluid conductor. Each one of the modules 220,independently, includes a module inlet 222 and a module outlet 224 andis configured for conducting reservoir fluid, received at the moduleinlet 222, from the module inlet 222 to the module outlet 224.

Each one of the modules 220, independently, also includes, a firsttubing 226, a second tubing 228, and a sealing member 230.

The second tubing 228 is disposed within the first tubing 226 such thatan intermediate space 232 is defined between the first tubing 226 andthe second tubing 228. In some embodiments, for example, the dispositionof the second tubing 228 within the first tubing 226 is such that thesecond tubing 228 is nested within the first tubing 226. In someembodiments, for example, the intermediate space 232 is an annularspace.

A sealed interface 230 is defined between the first tubing 226 and thesecond tubing 228. In some embodiments, for example, the sealedinterface 230 is effected by one or more sealing members that areretained within the intermediate space 232.

Referring to FIGS. 11A, 11B and 11C, in this respect, in someembodiments, the sealed interface is effected by a ring 240 that isinserted and retained within the intermediate space 232 and couples thefirst and second tubing 226, 228. The ring 240 includes a pair ofsealing members 230A, 230B. The sealing member 230A is retained within agroove 240A provided on an outermost surface 240B of the ring 240, andis disposed in sealing, or substantially sealing, engagement with thefirst tubing 226, while the sealing member 230B is retained within agroove 240C provided on an internal surface 240D of the ring 240, and isdisposed in sealing, or substantially sealing, engagement with thesecond tubing 228. The ring 240 is disposed in an interference fitrelationship relative to both of the first tubing 226 and the secondtubing 228. The ring 240 includes an outwardly flared lip 242 that isengageable to the first tubing 226. The ring 240 is integrated into theintermediate space 232 by insertion within the intermediate space 232 ina downhole direction while oriented with the flared lip 242 extendingoutwardly in the uphole direction. While moving in the downholedirection, the lip 242, due to its resiliency, is pressed inwardly anddoes not substantially interfere with movement of the ring 240 in thedownhole direction. Upon desired positioning of the sealing members230A, 230B, a force is applied to the ring 240 in an uphole direction,and the flared lip 242, while defining the sealed interface between thefirst tubing 226 and the second tubing 228.

An alternative ring 2401 is illustrated in FIGS. 12A, 12B, 12C and 12D.In this embodiment, the ring 2401 includes a plurality of grippers 2402that are biased outwardly, relative to the central longitudinal axis ofthe ring 2401, by resilient members 2404. In some embodiments, forexample, the resilient members 2404 are in the form of collet springs(for example, beam springs), that are separated by slots 2405. In someembodiments, for example, a gripper 2402 is disposed on a respectivecollet spring 2404. In some embodiments, for example, the gripper 2402is defined as a protuberance extending from the collet spring 2404. Insome embodiments, for example, the collet springs 2404 are configuredfor a limited amount of compression in response to a compressive forceapplied inwardly relative to a central longitudinal axis of the ring2401, as the ring 2401 is being inserted into the intermediate space 232in a downhole direction. Each one of the grippers 2402 extends outwardlyfrom the respective collet spring 2404, relative to the centrallongitudinal axis of the ring 2401, and terminates at a tip 2406 (suchas, for example, a sharp tip) configured to exert a gripping force onthe first tubing 226. Extension of the gripper 2402 from the colletspring 2404 is tapered in a downhole direction. This, in combinationwith the resiliency of the collet springs 2404, enables the ring 2401 tobe inserted into the intermediate space 232 in a downhole direction,without substantial interference by the gripper 2402. Upon desiredpositioning of the sealing members 230A, 230B (disposed in grooves2401A, C), a force is applied to the ring 2401 in an uphole direction,and the grippers 2402 become disposed in gripping engagement with thefirst tubing 226 with effect that the ring 2401 couples the first tubing226 to the second tubing 228, while defining the sealed interfacebetween the first tubing 226 and the second tubing 228.

In some embodiments, for example, the module inlet 222, the moduleoutlet 224, the first tubing 226, the second tubing 228, and the sealingmember 230 are co-operatively configured such that, while: the assembly10 is disposed within a wellbore and oriented such that the inlet 204 isdisposed downhole relative to the pump suction 302, the module isintegrated within the reservoir fluid-supplying conductor 206 such thatthe module inlet 222 is disposed downhole relative to the module outlet224, and reservoir fluid flow is being received by the module inlet 222while being conducted through the production string 202: (i) thereceived reservoir fluid flow is conducted, via the second tubing, tothe module outlet 224, and (ii) the sealed interface prevents, orsubstantially prevents, the received reservoir fluid, being conducted bythe second tubing 228, from bypassing the module outlet 224. In someembodiments, for example, the bypassing includes bypassing of the moduleoutlet 224 by flow in a downhole direction via the intermediate space232. In some embodiments, for example, the bypassing includes bypassingof the module outlet 224 by flow in a downhole direction via theintermediate space 232, towards the module inlet 222.

In some embodiments, for example, the module inlet 222, the moduleoutlet 224, the first tubing 226, the second tubing 228, and the sealingmember 230 are co-operatively configured such that, while: the assembly10 is disposed within a wellbore, and the module 220 is integratedwithin the reservoir fluid-supplying conductor 206 such that the moduleinlet 222 is disposed downhole relative to the module outlet 224: (i)reservoir fluid flow that is receivable by the module inlet 222 isconductible, via the second tubing 224, to the module outlet 224, and(ii) the sealing member 230 defines a sealed interface preventing, orsubstantially preventing, fluid communication, via the intermediatespace 232, between the module inlet 222 and the module outlet 224.

In some embodiments, for example, the module 220 includes a centralizer234. The second tubing 228 is centralized relative to the first tubing228 with the centralizer 234. In some embodiments, for example, thecentralizer 234 includes a C-clip.

In some embodiments, for example, the intermediate space 232 includes agas accumulation space 232A, disposed: (i) between the sealed interface230 and the module inlet 222, and (ii) in fluid communication with themodule inlet 222. When the module 220 is part of the assembly 10, thegas accumulation space 232A is disposed downhole relative to the sealedinterface 230. While: the assembly 10 is disposed within a wellbore andoriented such that the inlet 204 is disposed downhole relative to thepump suction 302, and the module 220 is integrated within the reservoirfluid-supplying conductor 206 such that the module inlet 222 is disposeddownhole relative to the module outlet 224, the presence of a gasaccumulation space 232A provides the opportunity for gaseous material,within the reservoir fluid received by the module inlet 222, toaccumulate within the gas accumulation space 232A. In some embodiments,for example, when the gas accumulation space 232 is sufficiently large,sufficient gaseous material is potentially collectible within the gasaccumulation space 232A such that, during transient periods when thepressure of the reservoir fluid received by the module inlet 222 becomessufficiently low, the accumulated gaseous material (which, in thesecircumstances, would be disposed at a greater pressure than thereservoir fluid being received by the module inlet 222) is induced toadmix with the reservoir fluid such that a gaseous slug is createdwithin the reservoir fluid flow. The presence of a gaseous slug withinthe reservoir fluid could be detrimental to the performance of theseparator 600, and, relatedly, is therefore, could be detrimental to theperformance of the pump 300. In this respect, in some embodiments, thepresence of a gas accumulation space 232A, when sufficiently large,could adversely affect production of the reservoir fluid.

To at least mitigate its detrimental effect on production, in someembodiments, for example, the volume occupied by the gas accumulationspace 232A is as small as possible. In some embodiments, for example,the total volume of the gas accumulation space 232A is less than 20%(such as, for example, less than 10%, such as, for example, less than5%), of the total volume of the intermediate space 232, and, in some ofthese embodiments, for example, there is an absence, or substantialabsence, of the gas accumulation space 232A.

In some embodiments, for example, the second tubing 228 includes asecond tubing inlet 228A for receiving reservoir fluid for theconducting by the second tubing 228, and the module inlet 222, themodule outlet 224, the first tubing 226, the second tubing 228, and thesealing member 230 are co-operatively configured such that, while: theassembly 10 is disposed within a wellbore, and the module 220 isintegrated within the reservoir fluid-supplying conductor 206 such thatthe module inlet 222 is disposed downhole relative to the module outlet224: the gas accumulation space 232A is disposed uphole of the secondtubing inlet 228A. In this respect, in some embodiments, for example,the gas accumulation space 232A is recessed relative to the secondtubing inlet 228. In some embodiments, for example, the establishment ofa gas accumulation space 232A is unavoidable, as the module 200 isoriginally configured with one end 220A defined by the second tubing228, and with the first tubing 226 spaced apart from the end 220A so asto permit for a re-cut of the end 220A. In some embodiments, forexample, the gas accumulation space 232A is defined by the positioningof the sealed interface 230 relative to the intermediate space 232, suchthat the positioning of the sealed interface 230 relative to theintermediate space 232 determines the volume occupied by the gasaccumulator space 232A.

Referring to FIGS. 13, 13A, 13B, 13C, 13D, 13E, 13F, 13G, 13H, 13J, 13K,13L, and 13M, in some embodiments, for example, the first tubing 226 andthe second tubing 228 are coupled together by mechanical interferencevia assembly 2200. In this respect, the assembly 2200 includes a coupler2202 (such as, for example, a slimhole coupler) and a threaded hanger2204 (see FIGS. 13C and 13D). The first tubing 226 is threadably coupledto the coupler 2202, and, co-operatively, the hanger 2204 is alsothreadably coupled to the coupler 2202. The second tubing 228 is flaredat its outlet 228B. The second tubing 228 and assembly 2200 areco-operatively configured such that the assembly 2200 limits downholemovement of the second tubing 228 relative to the first tubing 226 bymechanical interference between the hanger 2204 and the flared outlet228B. Relatedly, the second tubing 228 is crimped intermediate its inletand outlet ends 228A, 228B to define a mechanical interference-effectingportion 228F (such as, for example, in the form of a bulge). The secondtubing and the assembly 2200 are co-operatively configured such that theassembly 2200 limits uphole movement of the second tubing 228 relativeto the first tubing 226 by mechanical interference between the assembly2200 and the mechanical interference-effecting portion 228F. Morespecifically, the assembly 2200 additionally includes a spacer 2206 (seeFIGS. 13E and F), a sealing member 2208 (see FIGS. 13G and H; as well,for example, the sealing member 2208 includes a rubber bushing of Viton™material), and retainers 2210A, 2210B (see Figures J and K) disposed oneither side of the sealing member 2208. The spacer 2206, the sealingmember 2208, and the retainers 2210A, 2210B are pressed between thehanger 224 and the mechanical interference-effecting portion 228F. Inthis respect, the second tubing 228 is retained relative to the firsttubing 226 by virtue of the combination of the assembly 2200 and thecoupler 2202. As well, the sealed interface 230 is effected by sealingengagement of the sealing member 2208 to both of the first tubing 226and the second tubing 228.

In some embodiments, for example, the intermediate space 232 includes afluid accumulation space 232B, disposed: (i) between the sealedinterface 230 and the module outlet 224, and (ii) in fluid communicationwith the module outlet 224.

When the module 220 is part of the assembly 10, the fluid accumulationspace 232B is disposed downhole relative to the sealed interface 230.While: the assembly 10 is disposed within a wellbore and the module 220is integrated within the reservoir fluid-supplying conductor 206 suchthat the module inlet 222 is disposed downhole relative to the moduleoutlet 224, the presence of a fluid accumulation space 232B provides theopportunity for fluid material, including liquid material of thereservoir fluid received by the module inlet 222, to accumulate withinthe fluid accumulation space 232B. In some embodiments, suchaccumulation could result in corrosion of components of the assembly 10that are disposed in communication with the accumulated fluid. To atleast mitigate this corrosion, in some embodiments, for example, thevolume occupied by the fluid accumulation space 232B is as small aspossible. In some embodiments, for example, the total volume of thefluid accumulation space 232B is less than 20% (such as, for example,less than 10%, such as, for example, less than 5%), of the total volumeof the intermediate space 232, and, in some of these embodiments, forexample, there is an absence, or substantial absence, of the fluidaccumulation space 232B

In some embodiments, for example, the second tubing 228 is centralizedrelative to the first tubing 226 by a centralizer 2210 (see FIGS. 13Land M). The centralizer 2210 is disposed between and retained relativeto the first tubing 226 and the second tubing 228 by spaced-apartmechanical interference-effecting portions 228D, 228E (such as, forexample, spaced-apart bulges) that are formed by crimping of the secondtubing 228. The mechanical interference-effecting portions 228D, 228Eare disposed closer to the inlet end 228A relative to the mechanicalinterference-effecting portion 228F. Amongst other things, thecentralizer 2210 facilitates assembly of the module 220.

The assembly of the embodiment illustrated in FIG. 13 will now bedescribed. The second tubing 228 is inserted through the hanger 224, thespacer 2206, the retainer 2210A, the sealing member 2208, and theretainer 2210B. The outlet end 228B is then flared. After flaring, thehanger 224, the spacer 2206, the retainer 2210A, the sealing member2208, and the retainer 2210B are pushed up against the flare, and thesecond tubing 228 is crimped behind these components to obtain themechanical interference-effecting portion 228F, such that the hanger224, the spacer 2206, the retainer 2210A, the sealing member 2208, andthe retainer 2210B are retained relative to the second tubing 228between the flare and the mechanical interference-effecting portion228F. The second tubing 228 is also inserted through the centralizer2210, and then the mechanical interference-effecting portions 228D, 228Eare formed on either side of the centralizer 2210, such that thecentralizer 2210 becomes retained to the second tubing 228 between theportions 228D, 228E. The hanger 224 is then threaded to the coupler 2202such that the second tubing 228 becomes coupled to the coupler 2202 viathe hanger 224, to obtain an intermediate assembly. The intermediateassembly and the first tubing 226 are co-operatively manipulated suchthat the second tubing 228 becomes inserted into the first tubing 226,and the coupler 2202 becomes threadably coupled to the first tubing 226such that the second tubing 228 becomes coupled to the first tubing 226via the hanger 224 and the coupler 2202, and such that the sealedinterface 230 is established by sealing engagement of the sealing member2208 to both of the first tubing 226 and the second tubing 228.

As illustrated, in some embodiments, for example, the coupler 2202 ispart of a coupler that also function to effect coupling of the firsttubing 226 and the second tubing 228 of a second flow conductor module220, similarly as described above, and, in this respect, is also part ofanother flow control module 220. In the illustrated embodiment, thecoupler 2202 includes a first integration portion 2202A effectingcoupling of the first tubing 226 and the second tubing 228 of the module220, as shown, and also includes a second integration portion 2202A foreffecting coupling (not shown) of the first tubing 226 and the secondtubing 228 of another module 220

In some embodiments, for example, the second tubing 228 includes asecond tubing passage 228B, and the first tubing 226 includes a firsttubing passage 226A and the disposition of the second tubing 228 withinthe first tubing 226 is defined by a disposition of the second tubing228B within the first tubing passage 226A.

In some embodiments, for example, the second tubing includes a centrallongitudinal axis 228C, and the length of the second tubing 228, alongthe central longitudinal axis 228C is at least five (5) feet, such as,for example, at least ten (10) feet, such as, for example, at least 20feet.

In some embodiments, for example, the first tubing 226 defines anoutermost surface portion of the module 220.

By disposing the second tubing 228 within the first tubing 226, standardtubing (configured according to specifications of the American PetroleumInstitute (“API”)) can be used for the first tubing 226 to facilitatehandling and manipulation by standard oilfield tools, while the secondtubing 228 could be used to define a desirable cross-sectional flow areaso as to facilitate flow of the reservoir fluid at a desired speed. Insome embodiments, for example, the second tubing includes a section ofcoiled tubing.

As well, by providing a larger effective outside diameter, by disposinga relatively smaller diameter second tubing 228 within a relativelylarger diameter first tubing 226, it is easier to retrieve (such as, forexample, for the purposes of servicing) an assembly 10 that has beendeployed around a bend (such as, for example, at a kick-off point) suchthat a meaningful sump 124 is established. The larger diameter tubingprovides for more pull capacity.

In some embodiments, for example, two or more modules 220 areconnectible, end-to-end, such that at least a portion of the reservoirfluid-supplying conductor 206 includes the two or more modules 220. Inthis respect, in some embodiments, for example, the module 220 isconfigured for threaded connection. In some embodiments, for example,the module 220 includes first and second ends 220A, 220B, and each oneof the ends 220A, 220B, independently, includes an outer surface portionthat defines male threads. In some embodiments, for example, theconnecting of two modules 220 is effected by a threaded coupler 236. Insome embodiments, for example, the coupler 236 includes a centrallongitudinal axis 236A, and the central longitudinal axis 236A isdisposed in alignment, or substantial alignment, with the centrallongitudinal axis 228C of the second tubing 228.

In the above description, for purposes of explanation, numerous detailsare set forth in order to provide a thorough understanding of thepresent disclosure. However, it will be apparent to one skilled in theart that these specific details are not required in order to practicethe present disclosure. Although certain dimensions and materials aredescribed for implementing the disclosed example embodiments, othersuitable dimensions and/or materials may be used within the scope ofthis disclosure. All such modifications and variations, including allsuitable current and future changes in technology, are believed to bewithin the sphere and scope of the present disclosure. All referencesmentioned are hereby incorporated by reference in their entirety.

What is claimed is:
 1. A reservoir fluid conduction assembly fordisposition within a wellbore string, that is lining a wellbore that isextending into a subterranean formation, such that an intermediatewellbore space is defined within a space that is disposed between thewellbore string and the assembly, wherein the assembly includes: areservoir fluid-supplying conductor for conducting reservoir fluid thatis being received from a downhole wellbore space of the wellbore; a flowdiverter body including (a) a diverter body-defined reservoir fluidconductor for conducting reservoir fluid, that is supplied from thereservoir fluid-supplying conductor, to a reservoir fluid separationspace of an uphole wellbore space of the wellbore, the uphole wellborespace being disposed uphole relative to the downhole wellbore space, and(b) a diverter body-defined gas-depleted reservoir fluid conductor forreceiving gas-depleted reservoir fluid and conducting the receivedgas-depleted reservoir fluid for effecting supplying of the gas-depletedreservoir fluid to a gas-depleted reservoir fluid-producing conductor; asealed interface effector for co-operating with the wellbore string forestablishing a sealed interface a sealed interface for preventing, orsubstantially preventing, bypassing of the diverter body-definedgas-depleted reservoir fluid conductor by the separated gas-depletedreservoir fluid; and an anchor for coupling the assembly to the wellborestring; wherein: the flow diverter body, the sealed interface effector,the reservoir fluid-supplying conductor, and the anchor areco-operatively configured such that, while the assembly is coupled tothe wellbore string by the anchor, and disposed within the wellborestring such that the sealed interface is defined, and the reservoirfluid-supplying conductor is receiving reservoir fluid from the downholewellbore space that has been received within the downhole wellbore spacefrom the subterranean formation: the reservoir fluid is conducted to thediverter body-defined reservoir fluid conductor via the reservoirfluid-supplying conductor; the reservoir fluid is conducted by thediverter body-defined reservoir fluid conductor and discharged to areservoir fluid separation space of the uphole wellbore space; withinthe reservoir fluid separation space, a gas-depleted reservoir fluid anda gaseous material are separated from the discharged reservoir fluid, inresponse to at least buoyancy forces, such that the gas-depletedreservoir fluid and the separated gaseous material are obtained; theseparated gas-depleted reservoir fluid is conducted to the diverterbody-defined gas-depleted reservoir fluid conductor, via theintermediate wellbore space, for conduction to the surface via agas-depleted reservoir fluid producing conductor; and the separatedgaseous material is conducted to the surface via the intermediatewellbore space, and there is an absence, or substantial absence, ofopposition to conduction of the separated gaseous material to thesurface, via the intermediate wellbore space, by the anchor; and thereservoir fluid separation space defines a separation-facilitating spaceportion of the intermediate wellbore space.
 2. The assembly as claimedin claim 1; wherein the anchor is mounted to the flow diverter.
 3. Theassembly as claimed in claim 1 or 2; wherein the anchor is configuredsuch that, while the assembly is disposed within the wellbore andcoupled to the wellbore string with the anchor, one or moreflow-communicating spaces are defined between the anchor and thewellbore string.
 4. The reservoir fluid production assembly as claimedin any one of claims 1 to 3; wherein the anchor includes a tubinganchor.
 5. The assembly as claimed in any one of claims 1 to 4; wherein:the flow diverter body, the sealed interface effector, and the reservoirfluid conductor are further co-operatively configured such that, whilethe assembly is disposed within the wellbore string, such that thesealed interface is defined, and the diverter body-defined reservoirfluid conductor is receiving reservoir fluid that is received within thedownhole wellbore space from the subterranean formation, and conductedto the diverter body-defined reservoir fluid conductor via the reservoirfluid-supplying conductor: the conducting of the separated gas-depletedreservoir fluid to the diverter body-defined gas-depleted reservoirfluid conductor, via the intermediate wellbore space, is effected in adownhole direction.
 6. The assembly as claimed in any one of claims 1 to5; wherein: the flow diverter body, the sealed interface effector, andthe reservoir fluid-supplying conductor are further co-operativelyconfigured such that, while the assembly is disposed within the wellborestring, such that the sealed interface is defined, and the diverterbody-defined reservoir fluid conductor is receiving reservoir fluid thatis received within the downhole wellbore space from the subterraneanformation, and conducted to the diverter body-defined reservoir fluidconductor via the reservoir fluid-supplying conductor: at least aportion of the intermediate wellbore space, through which the separatedgas-depleted reservoir fluid is being conducted to the diverterbody-defined gas-depleted reservoir fluid conductor, is co-located withat least a portion of the separation-facilitating space portion.
 7. Theassembly as claimed in any one of claims 1 to 6; wherein: the assemblyfurther includes a gas-depleted reservoir fluid-producing conductor; andthe flow diverter body, the sealed interface effector, and the reservoirfluid-supplying conductor are further co-operatively configured suchthat, while the assembly is disposed within the wellbore string, suchthat the sealed interface is defined, and the diverter body-definedreservoir fluid conductor is receiving reservoir fluid that is receivedwithin the downhole wellbore space from the subterranean formation, andconducted to the diverter body-defined reservoir fluid conductor via thereservoir fluid-supplying conductor: the gas-depleted reservoir fluid,received by the diverter body-defined gas-depleted reservoir fluidconductor, is conducted to the gas-depleted reservoir fluid-producingconductor via the diverter body-defined gas-depleted reservoir fluidconductor, with effect that the gas-depleted reservoir fluid is suppliedto the gas-depleted reservoir fluid-producing conductor and conducted tothe surface via the gas-depleted reservoir fluid-producing conductor. 8.The assembly as claimed in claim 7; wherein: the assembly furtherincludes a pump for pressurizing the gas-depleted reservoir fluid; andthe pump is disposed within the gas-depleted reservoir fluid-producingconductor.
 9. The assembly as claimed in any one of claims 1 to 8;wherein: the flow diverter body further includes: a reservoir fluidreceiver for receiving the reservoir fluid being conducted by thereservoir fluid-supplying conductor from the downhole wellbore space; areservoir fluid discharge communicator; a gas-depleted reservoir fluidreceiver for receiving the separated gas-depleted reservoir fluid; and agas-depleted reservoir fluid discharge communicator; wherein: thediverter body-defined reservoir fluid conductor is effecting flowcommunication between the reservoir fluid receiver and the reservoirfluid discharge communicator, such that the disposition of the reservoirfluid within the reservoir fluid separation space is effectible bydischarging, via the reservoir fluid discharge communicator, of thereservoir fluid that is being received by the reservoir fluid receiver;and the diverter body-defined gas-depleted reservoir fluid conductor iseffecting flow communication between the gas-depleted reservoir fluidreceiver and the gas-depleted reservoir fluid discharge communicator,such that the supplying of the gas-depleted reservoir fluid to thesurface is effectible by discharging, via the gas-depleted reservoirfluid discharge communicator, of the gas-depleted reservoir fluid thatis being received by the gas-depleted reservoir fluid receiver.
 10. Theassembly as claimed in claim 9; wherein: the flow diverter body, thesealed interface effector, and the reservoir fluid-supplying conductorare further co-operatively configured such that, while the assembly isdisposed within the wellbore string, such that the sealed interface isdefined: the gas-depleted reservoir fluid receiver is disposed downholerelative to the reservoir fluid discharge communicator.
 11. The assemblyas claimed in claim 10; wherein the anchor is disposed between thegas-depleted reservoir fluid receiver and the reservoir fluid dischargecommunicator.
 12. The assembly as claimed in any one of claims 9 to 11;wherein: the flow diverter body, the sealed interface effector, and thereservoir fluid-supplying conductor are further co-operativelyconfigured such that, while the assembly is disposed within the wellborestring, such that the sealed interface is defined, and the diverterbody-defined reservoir fluid conductor is receiving reservoir fluid thatis received within the downhole wellbore space from the subterraneanformation, and conducted to the diverter body-defined reservoir fluidconductor via the reservoir fluid-supplying conductor: theseparation-facilitating space portion is disposed uphole relative to thereservoir fluid discharge communicator.
 13. The assembly as claimed inany one of claims 9 to 11; wherein: the flow diverter body, the sealedinterface effector, and the reservoir fluid-supplying conductor arefurther co-operatively configured such that, while the assembly isdisposed within the wellbore string, such that the sealed interface isdefined, and the diverter body-defined reservoir fluid conductor isreceiving reservoir fluid that is received within the downhole wellborespace from the subterranean formation, and conducted to the diverterbody-defined reservoir fluid conductor via the reservoir fluid-supplyingconductor: the separation-facilitating space portion includes: (i) anuphole-disposed space, and (ii) a flow diverter body-definedintermediate space; the uphole-disposed space is disposed upholerelative to the reservoir fluid discharge communicator; and the flowdiverter body-defined intermediate space is disposed between the flowdiverter body and the wellbore string.
 14. A reservoir fluid conductionassembly for disposition within a wellbore string, that is lining awellbore that is extending into a subterranean formation, wherein theassembly includes: a reservoir fluid-supplying conductor for conductingreservoir fluid that is being received from the subterranean formation;a gas separator, fluidly coupled to the reservoir fluid-supplyingconductor for receiving the reservoir fluid conducted by the reservoirfluid-supplying conductor, and effecting separation of gaseous materialfrom the reservoir fluid such that a gaseous-depleted reservoir fluidand a gaseous material are obtained; and an anchor for coupling theassembly to the wellbore string; wherein: the gas separator, thereservoir fluid-supplying conductor, and the anchor are co-operativelyconfigured such that, while the assembly is coupled to the wellborestring by the anchor, and the reservoir fluid-supplying conductor isreceiving reservoir fluid from the downhole wellbore space that has beenreceived within the downhole wellbore space from the subterraneanformation: the reservoir fluid is conducted to the separator via thereservoir fluid-supplying conductor; a gas-depleted reservoir fluid anda gaseous material are separated from the discharged reservoir fluid bythe separator; and the separated gaseous material is conducted to thesurface via the wellbore, wherein there is an absence, or substantialabsence, of opposition to flow of the separated gaseous material to thesurface, via the wellbore, by the anchor.
 15. The assembly as claimed inclaim 14; wherein the anchor is mounted to the gas separator.
 16. Areservoir fluid production system for producing reservoir fluid from asubterranean formation, comprising: a wellbore; a wellbore string thatis lining the wellbore; and the reservoir fluid conduction assembly asclaimed in any one of claims 1 to 15, disposed within wellbore string.17. A reservoir fluid production system for producing reservoir fluidfrom a subterranean formation, comprising: a wellbore; a wellbore stringthat is lining the wellbore; wherein: the wellbore includes a wellborespace; and the wellbore space includes a downhole wellbore space and anuphole wellbore space, wherein the uphole wellbore space is disposeduphole relative to the downhole wellbore space; and a reservoir fluidconduction assembly disposed within wellbore string and including: areservoir fluid-supplying conductor for receiving reservoir fluid fromthe downhole wellbore space; a gas-depleted reservoir fluid conductorfor receiving a gas-depleted reservoir fluid; an anchor for coupling theassembly to the wellbore string; wherein: the wellbore string and theassembly are co-operatively configured such that, while the downholewellbore space is receiving reservoir fluid from the subterraneanformation: the reservoir fluid is conducted by the reservoirfluid-supplying conductor to a reservoir fluid separation space of theuphole wellbore space with effect that a gas-depleted reservoir fluidand a gaseous material are separated from the reservoir fluid within thereservoir fluid separation space, in response to at least buoyancyforces, such that the gas-depleted reservoir fluid and the gaseousmaterial are obtained; the gas-depleted reservoir material is conductedto the gas-depleted reservoir fluid conductor with effect that thegas-depleted reservoir fluid is conducted through the gas-depletedreservoir fluid conductor to the surface; and the separated gaseousmaterial is conducted to the surface via the intermediate wellborespace, and there is an absence, or substantial absence, of opposition toconduction of the separated gaseous material to the surface, via theintermediate wellbore space, by the anchor.
 18. The system as claimed inclaim 17; wherein one or more flow-communicating spaces are definedbetween the anchor and the wellbore string.
 19. The reservoir fluidproduction assembly as claimed in claim 17 or 18; wherein the anchorincludes a tubing anchor.
 20. The system as claimed in any one of claims17 to 19; wherein the reservoir fluid separation space is disposeduphole relative to the reservoir fluid-supplying conductor.
 21. Thesystem as claimed in any one of claims 17 to 20, further comprising: aflow diverter including: (i) a reservoir fluid-diverting conductor forreceiving reservoir fluid from the downhole wellbore space andconducting the received reservoir fluid to the reservoir fluidseparation space, and (ii) a gas-depleted reservoir fluid-divertingconductor for receiving the separated gas-depleted reservoir fluid andconducting the received gas-depleted reservoir fluid for effecting thesupplying of the received gas-depleted reservoir fluid to the surface;wherein: the flow diverter includes a string counterpart and an assemblycounterpart; the wellbore string defines the string counterpart; theassembly defines the assembly counterpart; the reservoir fluid-divertingconductor defines at least a portion of the reservoir fluid-supplyingconductor; and the gas-depleted reservoir fluid-diverting conductordefines at least a portion of the gas-depleted reservoir fluidconductor.
 22. The system as claimed in claim 21; wherein the flowdiverter further includes a sealed interface for preventing, orsubstantially preventing, flow communication, between the downholewellbore space and the uphole wellbore space.
 23. The system as claimedin claim 21; wherein the flow diverter further includes a sealedinterface for preventing, or substantially preventing, bypassing of thegas-depleted reservoir fluid-diverting conductor by the separatedgas-depleted reservoir fluid.
 24. The system as claimed in claim 23;wherein the sealed interface is disposed for preventing, orsubstantially preventing, flow communication, between the downholewellbore space and the uphole wellbore space.
 25. The system as claimedin any one of claims 21 to 24; wherein the reservoir separation space isdisposed uphole relative to the flow diverter.
 26. The system as claimedin any one of claims 21 to 25; wherein the flow diverter is disposedwithin a vertical portion of the wellbore that extends to the surface.27. The system as claimed in any one of claims 21 to 26; wherein theassembly counterpart of the flow diverter further includes: a reservoirfluid receiver for receiving the reservoir fluid being conducted fromthe downhole wellbore space; a reservoir fluid discharge communicator;an assembly-defined reservoir fluid-diverting conductor effecting flowcommunication between the reservoir fluid receiver and the reservoirfluid discharge communicator, such that the disposition of the reservoirfluid within the reservoir fluid separation space is effectible bydischarging, via the reservoir fluid discharge communicator, of thereservoir fluid that is received by the reservoir fluid receiver agas-depleted reservoir fluid receiver for receiving the separatedgas-depleted reservoir fluid; a gas-depleted reservoir fluid dischargecommunicator; and an assembly-defined gas-depleted reservoirfluid-diverting conductor effecting flow communication between thegas-depleted reservoir fluid receiver and the gas-depleted reservoirfluid discharge communicator, such that the supplying of thegas-depleted reservoir fluid to the surface is effectible bydischarging, via the gas-depleted reservoir fluid dischargecommunicator, of the gas-depleted reservoir fluid that is received bythe gas-depleted reservoir fluid receiver; the assembly-definedreservoir fluid-diverting conductor defines at least a portion of thereservoir fluid-diverting conductor; and the assembly-definedgas-depleted reservoir fluid-diverting conductor defines at least aportion of the gas-depleted reservoir fluid-diverting conductor.
 28. Thesystem as claimed in claim 27; wherein the separation-facilitating spaceportion is disposed uphole relative to the reservoir fluid dischargecommunicator.
 29. The system as claimed in claim 27 or 28; wherein thegas-depleted reservoir fluid receiver is disposed downhole relative tothe reservoir fluid discharge communicator.
 30. The system as claimed inclaim 29; wherein the anchor is disposed between the gas-depletedreservoir fluid received and the reservoir fluid discharge communicator.31. A system including a reservoir fluid conduction assembly disposedwithin a wellbore string, that is lining a wellbore that is extendinginto a subterranean formation, such that an intermediate wellbore spaceis defined within a space that is disposed between the wellbore stringand the assembly, wherein the assembly includes: a reservoirfluid-supplying conductor for conducting reservoir fluid that is beingreceived from a downhole wellbore space of the wellbore; a flow diverterbody including (a) a diverter body-defined reservoir fluid conductor forconducting reservoir fluid, that is supplied from the reservoirfluid-supplying conductor, to a reservoir fluid separation space of anuphole wellbore space of the wellbore, the uphole wellbore space beingdisposed uphole relative to the downhole wellbore space, and (b) adiverter body-defined gas-depleted reservoir fluid conductor forreceiving gas-depleted reservoir fluid and conducting the receivedgas-depleted reservoir fluid for effecting supplying of the gas-depletedreservoir fluid to a gas-depleted reservoir fluid-producing conductor;and a sealed interface for preventing, or substantially preventing,bypassing of the diverter body-defined reservoir fluid conductor by theseparated gas-depleted reservoir fluid; wherein: the flow diverter body,the sealed interface effector, and the reservoir fluid-supplyingconductor are co-operatively configured such that, while the reservoirfluid-supplying conductor is receiving reservoir fluid from the downholewellbore space that has been received within the downhole wellbore spacefrom the subterranean formation: the reservoir fluid is conducted to thediverter body-defined reservoir fluid conductor via the reservoirfluid-supplying conductor; the reservoir fluid is conducted by thediverter body-defined reservoir fluid conductor and discharged to areservoir fluid separation space of the uphole wellbore space; withinthe reservoir fluid separation space, a gas-depleted reservoir fluid isseparated from the discharged reservoir fluid, in response to at leastbuoyancy forces; and the separated gas-depleted reservoir fluid isconducted to the diverter body-defined gas-depleted reservoirfluid-diverting conductor, via the intermediate wellbore space, forconduction to the surface via a gas-depleted reservoir fluid producingconductor; the reservoir fluid separation space defines aseparation-facilitating space portion of the intermediate wellborespace; the reservoir fluid-suppling conductor includes: a verticalsection-disposed portion having a central longitudinal axis that is lessthan 20 degrees relative to the vertical; a horizontal-section disposedportion having a central longitudinal axis that is between 70 and 110degrees relative to the vertical; and a transition section-disposedportion disposed between the vertical section-disposed portion and thehorizontal section-disposed portion and a cross-sectional area of thefluid passage of the transition section-disposed portion is less thanboth of: (i) a cross-sectional area of the fluid passage of the verticalsection-disposed portion, and (ii) a cross-sectional area of the fluidpassage of the horizontal section-disposed portion.
 32. The assembly asclaimed in claim 31; wherein the sealed interface prevents, orsubstantially prevents, flow communication, via the intermediatewellbore space, between the downhole wellbore space and the upholewellbore space.
 33. A system including a reservoir fluid-supplyingconductor, disposed within a wellbore, and including: a conductor inletfor receiving reservoir fluid flow from the wellbore; a verticalsection-disposed portion having a central longitudinal axis that is lessthan 20 degrees relative to the vertical; a horizontal section-disposedportion having a central longitudinal axis that is between 70 and 110degrees relative to the vertical; and a transition section-disposedportion that is disposed between the vertical and horizontal sections;wherein a cross-sectional area of the fluid passage of the transitionsection-disposed portion is less than both of: (i) a cross-sectionalarea of the fluid passage of the vertical section-disposed portion, and(ii) a cross-sectional area of the fluid passage of the horizontalsection-disposed portion.
 34. The system as claimed in any one of claims31 to 33; wherein the ratio of the minimum cross-sectional area of thefluid passage of the horizontal section-disposed portion to the maximumcross-sectional area of the fluid passage of the transition sectiondisposed portion is at least 1.1.
 35. The system as claimed in any oneof claims 31 to 34; wherein the ratio of the minimum cross-sectionalarea of the fluid passage of the vertical section-disposed portion tothe maximum cross-sectional area of the fluid passage of the transitionsection disposed portion is at least 1.1.
 36. The system as claimed inany one of claims 31 to 33; wherein: the ratio of the minimumcross-sectional area of the fluid passage of the horizontalsection-disposed portion to the maximum cross-sectional area of thefluid passage of the transition section disposed portion is at least1.1; and the ratio of the minimum cross-sectional area of the fluidpassage of the vertical section-disposed portion to the maximumcross-sectional area of the fluid passage of the transition sectiondisposed portion is at least 1.1.
 37. The system as claimed in any oneof claims 31 to 36; wherein the transition section-disposed portionextends along a curved path.
 38. The system as claimed in any one ofclaims 31 to 33; wherein: the vertical section-disposed portion includesan operative vertical section-disposed portion and the operativevertical section-disposed portion has a length, measured along thecentral longitudinal axis of the vertical section-disposed portion, thatis at least 50% of the length of the vertical section-disposed portionmeasured along the central longitudinal axis of the verticalsection-disposed portion; the transition section includes an operativetransition section portion and the operative transition section-disposedportion has a length, measured along the central longitudinal axis ofthe transition section-disposed portion, that is at least 50% of thelength of the transition section-disposed portion measured along thecentral longitudinal axis of the transition section-disposed portion;the horizontal section includes an operative horizontal section portionand the operative horizontal section-disposed portion has a length,measured along the central longitudinal axis of the horizontalsection-disposed portion, that is at least 50% of the length of thehorizontal section-disposed portion measured along the centrallongitudinal axis of the horizontal section-disposed portion; and theratio of the minimum cross-sectional area of the fluid passage of theoperative horizontal section-disposed portion to the maximumcross-sectional area of the fluid passage of the operative transitionsection disposed portion is at least 1.1.
 39. The system as claimed inany one of claims 31 to 33; wherein: the vertical section-disposedportion includes an operative vertical section-disposed portion and theoperative vertical section-disposed portion has a length, measured alongthe central longitudinal axis of the vertical section-disposed portion,that is at least 50% of the length of the vertical section-disposedportion measured along the central longitudinal axis of the verticalsection-disposed portion; the transition section includes an operativetransition section portion and the operative transition section-disposedportion has a length, measured along the central longitudinal axis ofthe transition section-disposed portion, that is at least 50% of thelength of the transition section-disposed portion measured along thecentral longitudinal axis of the transition section-disposed portion;the horizontal section includes an operative horizontal section portionand the operative horizontal section-disposed portion has a length,measured along the central longitudinal axis of the horizontalsection-disposed portion, that is at least 50% of the length of thehorizontal section-disposed portion measured along the centrallongitudinal axis of the horizontal section-disposed portion; and theratio of the minimum cross-sectional area of the fluid passage of theoperative vertical section-disposed portion to the maximumcross-sectional area of the fluid passage of the operative transitionsection disposed portion is at least 1.1.
 40. The system as claimed inany one of claims 31 to 33; wherein: the vertical section-disposedportion includes an operative vertical section-disposed portion and theoperative vertical section-disposed portion has a length, measured alongthe central longitudinal axis of the vertical section-disposed portion,that is at least 50% of the length of the vertical section-disposedportion measured along the central longitudinal axis of the verticalsection-disposed portion; the transition section includes an operativetransition section portion and the operative transition section-disposedportion has a length, measured along the central longitudinal axis ofthe transition section-disposed portion, that is at least 50% of thelength of the transition section-disposed portion measured along thecentral longitudinal axis of the transition section-disposed portion;the horizontal section includes an operative horizontal section portionand the operative horizontal section-disposed portion has a length,measured along the central longitudinal axis of the horizontalsection-disposed portion, that is at least 50% of the length of thehorizontal section-disposed portion measured along the centrallongitudinal axis of the horizontal section-disposed portion; the ratioof the minimum cross-sectional area of the fluid passage of theoperative horizontal section-disposed portion to the maximumcross-sectional area of the fluid passage of the operative transitionsection disposed portion is at least 1.1; and the ratio of the minimumcross-sectional area of the fluid passage of the operative verticalsection-disposed portion to the maximum cross-sectional area of thefluid passage of the operative transition section disposed portion is atleast 1.1.
 41. The system as claimed in any one of claims 38 to 40;wherein the transition section-disposed portion extends along a curvedpath.
 42. The system as claimed in any one of claims 31 to 41; whereinthe transition section joins the vertical section to the horizontalsection.
 43. A reservoir fluid conduction assembly for dispositionwithin a wellbore string, that is lining a wellbore that is extendinginto a subterranean formation, such that an intermediate wellbore spaceis defined within a space that is disposed between the wellbore stringand the assembly, wherein the assembly includes: a reservoirfluid-supplying conductor for conducting reservoir fluid that is beingreceived from a downhole wellbore space of the wellbore; a flow diverterbody including (a) a diverter body-defined reservoir fluid conductor forconducting reservoir fluid, that is supplied from the reservoirfluid-supplying conductor, to a reservoir fluid separation space of anuphole wellbore space of the wellbore, the uphole wellbore space beingdisposed uphole relative to the downhole wellbore space, and (b) adiverter body-defined gas-depleted reservoir fluid conductor forreceiving gas-depleted reservoir fluid and conducting the receivedgas-depleted reservoir fluid for effecting supplying of the gas-depletedreservoir fluid to a gas-depleted reservoir fluid-producing conductor;and a sealed interface effector for co-operating with the wellborestring for establishing a sealed interface for preventing, orsubstantially preventing, bypassing of the diverter body-definedreservoir fluid conductor by the separated gas-depleted reservoir fluid.wherein: the flow diverter body, the sealed interface effector, and thereservoir fluid-supplying conductor are co-operatively configured suchthat, while the assembly is disposed within the wellbore string, suchthat the sealed interface is defined, and the reservoir fluid-supplyingconductor is receiving reservoir fluid from the downhole wellbore spacethat has been received within the downhole wellbore space from thesubterranean formation: the reservoir fluid is conducted to the diverterbody-defined reservoir fluid conductor via the reservoir fluid-supplyingconductor; the reservoir fluid is conducted by the diverter body-definedreservoir fluid conductor and discharged to a reservoir fluid separationspace of the uphole wellbore space; within the reservoir fluidseparation space, a gas-depleted reservoir fluid is separated from thedischarged reservoir fluid, in response to at least buoyancy forces; andthe separated gas-depleted reservoir fluid is conducted to the diverterbody-defined gas-depleted reservoir fluid conductor, via theintermediate wellbore space, for conduction to the surface via agas-depleted reservoir fluid producing conductor; the reservoir fluidseparation space defines a separation-facilitating space portion of theintermediate wellbore space; and the reservoir fluid-supplying conductorincludes a contoured section that is contoured with effect that, while areservoir fluid is being flowed through the reservoir fluid-supplyingconductor, a swirl in the reservoir fluid flow is induced.
 44. Theassembly as claimed in claim 43; wherein the sealed interface isdisposed for preventing, or substantially preventing, flowcommunication, via the intermediate wellbore space, between the downholewellbore space and the uphole wellbore space.
 45. A reservoir fluidconduction assembly for disposition within a wellbore that is extendinginto a subterranean formation, wherein the assembly comprises: areservoir fluid-supplying conductor for conducting reservoir fluid thatis being received from the subterranean formation; a gas separator,fluidly coupled to the reservoir fluid-supplying conductor for receivingthe reservoir fluid conducted by the reservoir fluid-supplyingconductor, and effecting separation of gaseous material from thereservoir fluid such that a gaseous-depleted reservoir fluid isobtained; and wherein: the gas separator and the reservoirfluid-supplying conductor are co-operatively configured such that, whilethe assembly is disposed within the wellbore, and the reservoirfluid-supplying conductor is receiving reservoir fluid from the wellborethat has been received within the wellbore from the subterraneanformation: the reservoir fluid is conducted to the gas separator via thereservoir fluid-supplying conductor; and gaseous material is separatedfrom the discharged reservoir fluid by the separator such that agas-depleted reservoir fluid is obtained; and the reservoirfluid-supplying conductor includes a contoured section that is contouredwith effect that, while a reservoir fluid is being flowed through thereservoir fluid-supplying conductor, a swirl in the reservoir fluid flowis induced.
 46. A reservoir fluid conduction assembly, disposed within awellbore, wherein the reservoir fluid conduction assembly comprises: areservoir fluid-supplying conductor for conducting reservoir fluid thatis being received from the subterranean formation; wherein: thereservoir fluid-supplying conductor includes a contoured section that iscontoured with effect that, while a reservoir fluid is being flowedthrough the reservoir fluid-supplying conductor, a swirl in thereservoir fluid flow is induced.
 47. The reservoir fluid-conductingassembly as claimed in any one of claims 43 to 46; wherein thecontouring is defined by a rifled groove.
 48. The reservoirfluid-conducting assembly as claimed in any one of claims 43 to 46;wherein the contouring is defined by a helical rifled groove.
 49. Thereservoir fluid-conducting assembly as claimed in claim 47 or 48;wherein the rifled groove has a minimum depth of 0.1 centimeters. 50.The reservoir fluid-conducting assembly as claimed in any one of claims47 to 49; wherein the rifled groove has a pitch of between 30 degreesand 60 degrees.
 51. The reservoir fluid-conducting assembly as claimedin any one of claims 43 to 50; wherein the contouring is defined on aninternal surface of the contoured section.
 52. The reservoirfluid-conducting assembly as claimed in any one of claims 43 to 51;wherein the contoured section has a length of at least five (5) feetalong the central longitudinal axis of the fluid passage of thecontoured section.
 53. The reservoir fluid-conducting assembly asclaimed in any one of 43 to 52; wherein the swirl is disposed about thecentral longitudinal axis of the fluid passage of the contoured section.54. The reservoir fluid-conducting assembly as claimed in any one of 43to 53; wherein the reservoir fluid-supplying conductor includes avelocity string, and the velocity string includes the contoured section.55. The reservoir fluid conducting assembly as claimed in any one ofclaims 43 to 54; wherein the reservoir fluid receiver is disposeddownhole relative to the reservoir fluid discharge communicator.
 56. Thereservoir fluid conducting assembly as claimed in any one of claims 43to 55; wherein the gas-depleted reservoir fluid receiver is disposedbelow the reservoir fluid discharge communicator.
 57. The reservoirfluid conducting assembly as claimed in any one of claims 43 to 56;wherein the reservoir fluid receiver is disposed downhole relative tothe reservoir fluid discharge communicator.
 58. The reservoir fluidconducting assembly as claimed in any one of claims 43 to 57; whereinthe gas-depleted reservoir fluid receiver is disposed below thereservoir fluid discharge communicator.
 59. A reservoir fluid conductionassembly for disposition within a wellbore string, that is lining awellbore that is extending into a subterranean formation, such that anintermediate wellbore space is defined within a space that is disposedbetween the wellbore string and the assembly, wherein the assemblyincludes: a reservoir fluid-supplying conductor, for conductingreservoir fluid that is being received from a downhole wellbore space ofthe wellbore, and including a fluid conductor subassembly that includes:a first tubing defining a conductor inlet; a second tubing disposedwithin the first tubing such that an intermediate subassembly space isdefined between the first tubing and the second tubing; and asubassembly sealed interface disposed within the intermediatesubassembly space between the first tubing and the second tubing; a flowdiverter body including (a) a diverter body-defined reservoir fluidconductor for conducting reservoir fluid, that is supplied from thereservoir fluid-supplying conductor, to a reservoir fluid separationspace of an uphole wellbore space of the wellbore, the uphole wellborespace being disposed uphole relative to the downhole wellbore space, and(b) a diverter body-defined gas-depleted reservoir fluid conductor forreceiving gas-depleted reservoir fluid and conducting the receivedgas-depleted reservoir fluid for effecting supplying of the gas-depletedreservoir fluid to a gas-depleted reservoir fluid-producing conductor;and a sealed interface effector for co-operating with the wellborestring for establishing a sealed interface for preventing, orsubstantially preventing, bypassing of the diverter body-definedreservoir fluid conductor by the separated gas-depleted reservoir fluid;wherein: the flow diverter body, the sealed interface effector, and thereservoir fluid-supplying conductor are co-operatively configured suchthat, while the assembly is disposed within the wellbore string, suchthat the sealed interface is defined, and the reservoir fluid-supplyingconductor is receiving reservoir fluid from the downhole wellbore spacethat is being received within the downhole wellbore space from thesubterranean formation: reservoir fluid is conducted, via the reservoirfluid-supplying conductor, including via the second tubing, to thediverter body-defined reservoir fluid conductor; while the conducting ofthe reservoir fluid is being effected via the second tubing, thesubassembly sealed interface prevents, or substantially prevents, thereservoir fluid, being conducted by the second tubing, from bypassingthe diverter body-defined reservoir fluid conductor; the reservoir fluidis conducted by the diverter body-defined reservoir fluid conductor anddischarged to a reservoir fluid separation space of the uphole wellborespace; within the reservoir fluid separation space, a gas-depletedreservoir fluid is separated from the discharged reservoir fluid, inresponse to at least buoyancy forces; and the separated gas-depletedreservoir fluid is conducted to the diverter body-defined gas-depletedreservoir fluid conductor, via the intermediate wellbore space, forconduction to the surface via a gas-depleted reservoir fluid producingconductor; the reservoir fluid separation space defines aseparation-facilitating space portion of the intermediate wellborespace.
 60. The assembly as claimed in claim 59; wherein the sealedinterface is disposed for preventing, or substantially preventing, flowcommunication, via the intermediate wellbore space, between the downholewellbore space and the uphole wellbore space.
 61. The assembly asclaimed in claim 60 or 61; wherein the bypassing of the diverterbody-defined reservoir fluid conductor includes bypassing of thediverter body-defined reservoir fluid conductor by conduction of thereservoir fluid in a downhole direction via the intermediate subassemblyspace.
 62. A reservoir fluid conduction assembly for disposition withina wellbore that is extending into a subterranean formation, wherein theassembly includes: a reservoir fluid-supplying conductor, for conductingreservoir fluid that is being received from the subterranean formationvia the wellbore, and including a fluid conductor subassembly thatincludes: a first tubing defining a conductor inlet; a second tubingdisposed within the first tubing such that an intermediate subassemblyspace is defined between the first tubing and the second tubing; and asubassembly sealed interface disposed within the intermediatesubassembly space between the first and second tubing; and a gasseparator, fluidly coupled to the reservoir fluid-supplying conductorfor receiving the reservoir fluid conducted by the reservoirfluid-supplying conductor, and effecting separation of gaseous materialfrom the reservoir fluid such that a gaseous-depleted reservoir fluid isobtained; wherein: the gas separator and the reservoir fluid-supplyingconductor are co-operatively configured such that, while the assembly isdisposed within the wellbore, and the reservoir fluid-supplyingconductor is receiving reservoir fluid from the wellbore that has beenreceived within the wellbore from the subterranean formation: thereservoir fluid is conducted, via the reservoir fluid-supplyingconductor, including via the second tubing, to the separator; while theconducting of the reservoir fluid is being effected via the secondtubing, the subassembly sealed interface prevents, or substantiallyprevents, the reservoir fluid, being conducted by the second tubing,from bypassing the diverter body-defined reservoir fluid conductor; andgaseous material are separated from the discharged reservoir fluid bythe separator such that gas-depleted reservoir fluid is obtained. 63.The assembly as claimed in claims 59 to 62; wherein the bypassing of thediverter body-defined reservoir fluid conductor includes bypassing ofthe diverter body-defined reservoir fluid conductor by conduction of thereservoir fluid in a downhole direction via the intermediate subassemblyspace.
 64. The assembly as claimed in any one of claims 59 to 63;wherein: a fluid accumulation space, if any, of the intermediateassembly space, and disposed: (i) between the sealed interface and themodule outlet, and (ii) in fluid communication with the module outlet,occupies a total volume that is less than 20% of the total volume of theintermediate assembly space.
 65. The assembly as claimed in any one ofclaims 59 to 63; wherein: a gas accumulation space, if any, of theintermediate assembly space, and disposed: (i) between the sealedinterface and the module inlet, and (ii) in fluid communication with themodule inlet, occupies a total volume that is less than 20% of the totalvolume of the intermediate assembly space.
 66. The assembly as claimedin any one of claims 59 to 65; wherein the second tubing passageincludes a minimum length of at least five (5) feet, measured along thecentral longitudinal axis of the second tubing passage.
 67. The assemblyas claimed in any one of claims 59 to 66; wherein: the first tubingdefines an outermost surface of the reservoir fluid-supplying conductor;and the first tubing is configured according to API specifications. 68.A fluid production assembly comprising a plurality of fluid conductormodules connected end to end, wherein each one of the fluid conductormodules, independently, includes: a first tubing; a second tubingdisposed within the first tubing such that an intermediate space isdefined between the first tubing and the second tubing; and asubassembly sealed interface disposed between the first tubing and thesecond tubing.
 69. The fluid production assembly as claimed in claim 68;wherein the second tubing passage includes a minimum length of at leastfive (5) feet, measured along the central longitudinal axis of thesecond tubing passage.
 70. The fluid production assembly as claimed inclaim 68 or 69; wherein: the first tubing defines an outermost surfaceof the fluid conductor module; and the first tubing is configuredaccording to API specifications.
 71. A fluid conductor modulecomprising: a first tubing; a second tubing disposed within the firsttubing such that an intermediate space is defined between the firsttubing and the second tubing; and a subassembly sealed interfacedisposed between the first tubing and the second tubing.
 72. The fluidproduction module as claimed in claim 71; wherein the second tubingpassage includes a minimum length of at least five (5) feet, measuredalong the central longitudinal axis of the second tubing passage. 73.The fluid production module as claimed in claim 71 or 72; wherein: thefirst tubing defines an outermost surface of the fluid productionmodule; and the first tubing is configured according to APIspecifications.
 74. A method of producing reservoir fluid using any oneof the assemblies, systems, or modules as claimed in any one of claims 1to 73.